ANNUAL REPORT - Infraline

ANNUAL REPORT 

2008-09 

Government of India 

Ministry of Power 

Central Electricity Authority

Annual Report 

2008-09 

Government of India 

Ministry of Power 

Central Electricity Authority 

July 2009

Central electricity authority Annual Report 2008-09 

Sub ordinate Offices : 

Regional Power Committees: 

Central Electricity Authority 

Sewa Bhawan, R.K. Puram 

New Delhi – 110 066 

CEA website: www.cea.nic.in 

1. Member Secretary, Northern Regional Power Committee, 18-A, Shaheed Jit Singh Marg, 

Katwaria Sarai, New Delhi-110016. 

2. Member Secretary, Western Regional Power Committee, Plot No. F-3, Opposite SEEPZ Complex, 

MIDC Area Marol, Andheri (East), Mumbai-400093. 

3. Member Secretary, Southern Regional Power Committee, 29 Race Course Cross Road, Near 

Anand Rao Circle, Bangalore-560009. 

4. Member Secretary, Eastern Regional Power Committee, 14 Golf Club Road, Tollygunge, 

Kolkata-700033. 

5. Member Secretary, North-Eastern Regional Power Committee, Nongrimbah Road, Laitumkhrah, 

Shillong-793003. 

Regional Power Survey Offices: 

1. Dy. Director, Regional Power Survey Office (North), 3 rd Floor, 18-A, Shaheed Jit Singh Marg, 

Katwaria Sarai, New Delhi-110016. 

2. Dy. Director, Regional Power Survey Office (South), Letter Box No. 38, 6 th Floor, ‘F’ Wing, 

Kendriya Sadan, Koramangala, Bangalore – 560034. 

3. Dy. Director, Regional Power Survey Office (West), 5 th Floor, Plot No. F-3, Opposite SEEPZ 

Complex, MIDC Area Marol, Andheri (East), Mumbai-400093. 

4. Dy. Director, Regional Power Survey Office (East), Room No.201, C.G.O. Complex, ‘DF’- 

Block, Salt Lake City, Kolkata-700064. 

Regional Inspectorial Organisations: 

1. Superintending Engineer, Regional Inspectorial Organisation (North), 18-A, Shaheed Jit Singh 

Marg, Katwaria Sarai, New Delhi-110016. 

2. Superintending Engineer, Regional Inspectorial Organisation (West), Ground Floor, WRPC 

Building, F-3, MIDC Area Marol, Andheri (East), Mumbai-400093. 

3. Superintending Engineer, Regional Inspectorial Organisation (South), Shastri Bhawan, Chennai- 

600006. 

4. Superintending Engineer, Regional Inspectorial Organisation (East), 14 Golf Club Road, 

Tollygunge, Kolkata-700033. 

5. Superintending Engineer, Regional Inspectorial Organisation (North-East), “Aprem” near Miza 

Modern High School, Nongrim Hills, Shillong-793003.


From the Chairperson 

The year 2008-09 was globally the year of economic slowdown. The Power 

Sector in India registered a growth of 2.74% with gross power generation by 

various utilities being 724 Billion kWh as against the previous year power 

generation of 704 Billion kWh. The growth would have been higher but for less 

inflows at hydro power stations due to poor monsoon and shortage of fuel. 

The definition of commissioning of generating units was revised by CEA 

during the year. Earlier a unit was declared commissioned after synchronization 

with grid. It was observed that the thermal units were being synchronized by 

adopting some temporary measures and it took very long to achieve full load 

on the designated fuel. It was, therefore, decided to modify the definition of 

commissioning. A unit is now declared commissioned only after it has attained 

full load on the designated fuel. 

During the year, a total of 3454 MW generation capacity was added which comprised 969 MW 

hydro and 2,485 MW thermal, thus raising the Installed Capacity of the country to 1, 47,965 MW. 

The Construction Monitoring groups of CEA were constrained by non-availability of IT based 

monitoring system at the project level which is essential for effective monitoring. CEA has been 

following up with BHEL and project developers for IT based monitoring but not much progress has 

been made in this direction. 

CEA teams also visited BHEL works during the year to review the progress of augmentation of 

manufacturing capacity and programme for supply of equipment for the 11 th Plan Projects. While 

considerable progress was seen at Trichy, serious delays in augmentation plan and consequently in 

supply schedule of Turbine-Generator modules at Hardwar Plant of BHEL were identified. BHEL was 

requested to outsource finished/semi-finished T-G modules to meet the supply schedules of power 

projects and also airlift the equipment to save transportation time. BHEL accepted our proposal 

and took action to outsource and airlift the modules. Despite this, supply of T-G modules remains 

critical to a number of 500 MW units at coal fired thermal projects. 

With a view to encourage transfer of technology and indigenous manufacturing of Steam 

Generator and Turbine-Generator with super critical technology, CEA has proposed bulk tendering 

of 11 units of 660 MW with mandatory indigenous phase manufacturing. CEA after discussion 

with the prospective manufacturing companies and after visiting manufacturing works of leading 

Steam Generator and Turbine-Generator manufacturers prepared pre-qualification requirements 

and mandatory phased manufacturing programme to be followed by the bidders participating in the 

bulk tendering. After approval from Government of India, the bidding process of Bulk Tendering 

of the super-critical units is under process. This will facilitate technology transfer and setting up of 

manufacturing facilities for thermal units with super critical technology by two or three manufacturers. 

Setting up of indigenous manufacturing facilities will help in meeting the requirement of the country 

for the 12 th Plan and beyond. 

CEA in consultation with utilities and industry reviewed the pre-qualification requirements 

for Balance of Plants and issued guidelines to all the utilities to facilitate development of additional 

manufacturing facilities by new entrepreneurs. 

A number of IPPs propose to set up generating plants in various States viz. hydro projects in 

hill states of Himachal Pradesh, Uttarakhand and in Arunachal Pradesh; thermal projects in Orissa, 

Chhattisgarh, Jharkhand and Madhya Pradesh; coastal projects in Southern and Western Regions. 

CEA prepared composite transmission plan for evacuation of power from the proposed projects which


could be developed in a phased manner along with the development of the generation projects. 

Power and coal mining projects have long gestation period. Thus, advance planning of 

development of power sector is necessary. CEA has already started planning studies for the 12 th and 

13 th Plans. 

CEA/Ministry of Power had instituted a Comprehensive Award Scheme for efficient and 

economic operation of thermal, hydro and nuclear power stations, transmission system and power 

distribution companies as also for generation and transmission projects executed in time. During the 

year, an additional Award for Environment Friendly Thermal Power Station has been introduced. 

One of the functions of CEA is to give concurrence to hydro projects. During the year 2008-09, 

CEA had appraised and accorded concurrence to 4 Nos. Hydro Generation schemes aggregating to 860 

MW capacity with an estimated financial cost of Rs.4020 Crores. CEA prepared Hydro Development 

Plan for the 12 th Five Year Plan identifying shelf of 109 candidate hydro projects for the 12 th Plan 

with aggregate capacity of over 30,000 MW. It is our endeavour that all clearances for the 12 th Plan 

projects are obtained and orders are placed for main packages during the 11 th Plan itself to ensure 

their commissioning during the 12 th Plan. Similarly, shelf of thermal projects and coal blocks have 

also been identified for similar action. 

Besides the statutory obligations, CEA rendered engineering and consultancy to the utilities 

in India and in neighbouring countries. 

To deal with the cases under Right to Information Act, the Public Information Officers, Assistant 

Public Information Officers and the Appellate Authority have been notified for all the offices at 

Headquarter and Sub-ordinate offices. During the year 2008-09, 90 Nos. of requests/ applications 

were received and 93 Nos. have been decided including 7 Nos. of cases received before this period. 

4 Nos. of cases are under process. 

All out efforts are being made to enhance the usage of Hindi in official work in all the offices of 

CEA. All incentive schemes sponsored by the Deptt. of Official Language are in operation in CEA. In 

addition, a Roving Shield is awarded to the Division/Section/Unit which does maximum work in Hindi 

throughout the year. CEA has introduced a Cash Award Scheme namely ‘Kendriya Vidyut Pustak Lekhan 

Puraskar Yojna’ on an All India basis to promote original book writing in Hindi from the calendar year 

2003. The prize money under this scheme has been further increased to: (A) First Prize - Rs. 60,000/-, 

(B) Second Prize - Rs.40,000/- (C) Third Prize - Rs.25,000/- and one consolation prize of Rs.10,000/- 

has been introduced from this year. 

During the year, 23 power training institutes/centres of various SEBs/Utilities were accorded 

recognition/renewal for ensuring development of training infrastructure in the Power Sector and to 

make available trained and skilled manpower for meeting the requirements of construction, operation 

and maintenance in the Power Sector. The scheme of adoption of ITIs by the project developers in 

the vicinity of the project was introduced in July 2007. Eight Central Power Sector Utilities have 

adopted 51 ITIs to provide quality man power for the Power Sector. 

In the end, I take this opportunity to express my deep appreciation for the committed efforts put 

in by one and all in the Power Sector in accomplishment of the above tasks and look forward with 

the hope that CEA officials will continue to work with the same zeal, devotion and co-operation for 

development of the Power Sector in the country. 

(Rakesh Nath) 

Chairperson, CEA


the authority 

Shri Rakesh Nath 

Chairperson, CEA 

Sh. V.S. Verma 

Member (Planning) 

Shri Gurdial Singh 

Member (Hydro) 

Shri V. Ramakrishna 

Member (Power System) 

Shri R. Dahiya 

Member (Thermal) 

Shri Sunil Verma 

Member (E&C) 

Shri S.M. Dhiman 

Member (G.,O.&D)


(As on 31-03-2009) 

Chairperson (CEA) 

(Rakesh Nath) 

Chief Engineer 

(Co-ordination) 


(HRD) 

Member 

(Thermal) 

(Vacant ) 

Member 

(Grid Op. & Distn.) 

(S.M. Dhiman) 

Member 

(Economic & Comm.) 

(Sunil Verma ) 

Member 

(Power System) 

(V. Ramakrishna) 


(Thermal Plg. & 

Investigation) 


(Grid Management) 


(Financial & 

Commercial Appraisal) 


(System Planning 

& Project Appraisal) 


(Thermal Engg. & Tech. 

Development) 


(Thermal Project 

Monitoring) 


(Thermal Renovation 

& Modernisation) 


(Thermal Civil Design) 


(Operation Performance 

Monitoring) 


(Load Dispatch & 

Telecomm.) 


(Distribution Plg. & 

Development ) 


(Information Technology) 

MS (NRPC) 

Economic Adviser 

(Economic Policy) 


(Financial Studies & 

Appraisal) 


(Legal) 


(System Engg. & Tech. 

Development) 


(Power System Project 

Monitoring) 


(Electrical Inspectorate) 

SE (RIO-North) 

SE (RIO-West) 

MS (WRPC) 

SE (RIO-South) 

MS (SRPC) 

SE (RIO-East) 

MS (ERPC) 

SE (RIO-North East) 

MS (NERPC) 

Secretary (CEA) 

(K.P. Singh ) 

Member 

(Hydro) 

(Gurdial Singh) 


(Hydro Plg. & 

Investigation) 


(Hydro Project 

Appraisal) 


(Hydro Project 

Monitoring) 


(Hydro Engg & 

Renovation / 

Modernization) 


(Hydro Engg. & 

Tech. Development) 

RPSO (East) 

RPSO (North) 

RPSO (South) 

Member 

(Planning) 

(Vacant ) 


(Integrated Resource 

Planning) 

N.E. Cell 


(Research & Development) 


(Conservation & Efficiency) 


(Operation Monitoring) 


(Data Management and 

Load Forecasting) 

RPSO (West)


Title 

Index 

Page No. 

Chapter – 1 Organisation 1 

Chapter – 2 Planning For Power Development 19 

Chapter – 3 Power Systems Planning and Development 40 

Chapter – 4 Grid Management 58 

Chapter – 5 Hydro Power Development 69 

Chapter – 6 Thermal Power Development 79 

Chapter – 7 Distribution and Rural Electrification 89 

Chapter – 8 Design & Engineering Services 95 

Chapter – 9 Economic and Commercial Aspects of the Power Industry 99 

Chapter – 10 Power Generation 113 

Chapter – 11 Power Development in North-Eastern Region 119 

Chapter – 12 Training and Human Resource Development 132 

Annexure-2a Status of Projects under National Perspective Plan on Power Sector 137 

Annexure-2b Awardees for the year 2007-08 138 

Annexure-2C Coal Blocks allocated to power utilities 139 

Annexure -3a 

Details of Inter-Regional Transmission capacity – Existing 

and planned for 11th Plan 

Annexure-3b Exhibit-I – Master Plan for Uttarakhand Projects 144 

Exhibit-II - Master Plan of Evacuation System for Projects in Satluj 145 

Basin 

Exhibit-III - Master Plan of Evacuation System for Projects in Rabi 146 

Basin 

Exhibit-IV - Master Plan of Evacuation System for Projects in Beas 147 

Basin 

Exhibit-V – Transmission System for Evacuation of Power from 148 

Hydro Projects in Sikkim 

Exhibit-VI – Transmission System Plan for Generation Projects 149 

located in Orissa, Jharkhand, Chhattisgarh, M.P. and Maharashtra 

Exhibit-VII – Southern Region Transmission Corridors for evacuation 150 

of IPP Generation 

Exhibit-VIII – Master Plan for Hydro Electric Projects in Arunachal 151 

Pradesh 

Annexure-3c Issues pertaining to Transmission System Planning discussed/Resolved 

during 2008-09 

152 

142


Title 

Page No. 

Annexure-3D Transmission Lines completed during the year 2008-09 156 

Annexure-3E Sub-Stations commissioned during the year 2008-09 162 

Annexure-4a Power Supply Position during 2008-09 166 

Annexure-4b Status of Capacitor Installation as on 31.3.2009 168 

Annexure-5a PFRs under 50,000 MW Hydroelectric Initiative 169 

Annexure-5b Hydro capacity addition during 2008-09 170 

Annexure-5c Hydro capacity addition programme for the year 2009-10 173 

Annexure-5d Hydro Projects identified for benefits during 12th Plan Cost reduction 176 

achieved by CEA in hard cost & soft cost at the time of according 

concurrence to various hydro power projects during 2007-08 

Annexure-5E Hydro Electric Schemes concurred by CEA during 2008-09 180 

Annnexure -6a Projects based on Tariff Based Competitive Bidding (Case-II) by States 181 

Annexure –6b Thermal Units Target & Achievement during 2008-09 182 

Annexure-6c Thermal Capacity Addition Programme for the year 2009-10 183 

Annexure-6D Units identified for Energy Efficient R & M 186 

Annexure-8a Hydro Power Stations in operation for which Consultancy Services have 188 

been rendered by CEA 

Annexure-8b Projects for which Design & Engineering Services were provided during 191 

2008-09 

Annexure-9a Outstanding dues payable to CPSUs 193 

Annexure-9b State-wise estimated Average Rates Of Electricity 194 

Annexure-9C (i) Cost of Energy Generation during 2000-01 to 2005-06 

(ii) Cost of Generation of Power for the year 2006-07 

(iii) Rate of Sale of Power of Generating Stations in the country for the 

year 2007-08 

197 

Annexure-10a All India / Sector-wise / Organization-wise Generation Target / Actual 212 

for 2008-09 

Annexure-10b State-wise/ Region-wise/ Sector-wise / Prime Mover-wise Installed 216 

Capacity for the year 2008-09 

Annexure-11a 50,000 MW Hydroelectric Initiative Low tariff HE Schemes under Survey 222 

& Investigation/ Preparation of DPR in North-eastern Region 

Annexure-11b Details of new Thermal Power Projects in North-eastern States 225 

Annexure-12a Tour/ Training abroad of CEA Officers during 2008-09 226


CHAPTER – 1 

ORGANISATION 

1.1 Organisation of CEA 

1.1.1 The Central Electricity Authority (CEA) 

is a statutory organisation originally constituted 

under section 3(1) of the repealed Electricity 

(Supply) Act, 1948 since substituted by section 

70 of the Electricity Act, 2003. It was established 

as a part- time body in the year 1951 and made a 

full- time body in the year 1975. 

1.1.2 As per section 70(3) of the Electricity Act, 

2003, Authority shall consist of not more than 14 

members (including its Chairperson) of whom 

not more than eight shall be full-time Members 

to be appointed by the Central Government. 

1.1.3 CEA is headed by a Chairperson who as 

the Chief Executive of the Authority largely 

oversees the development of Power Sector 

in the country. A Secretary, appointed by the 

Authority with the approval of the Central 

Government under section 72 of Electricity Act 

2003, assists the Chairperson in discharging of 

CEA’s statutory functions. The Secretary also 

assists the Chairperson in all matters pertaining 

to administration and technical matters including 

human resource development and concurrence 

of hydro power projects etc. There are six (6) 

Wings in CEA namely Planning, Hydro, Thermal, 

Grid Operation & Distribution, Economic & 

Commercial and Power System each headed 

by a Member of the Authority. Under each 

Member, there are technical Divisions, headed 

by an officer of the rank of Chief Engineer. At 

present, there are twenty-nine Divisions in CEA 

headquarter at New Delhi. 

1.1.4 Sub-ordinate offices of CEA 

There are 14 subordinate offices of CEA 

viz. five (5) Regional Inspectorial Organizations, 

four (4) Regional Power Survey Organizations 

and five (5) Regional Power Committees located 

in various parts of the country. 

A) Regional Inspectorial Organisation 

(RIO) 

Under Chief Engineer (EI) in Power 

System Wing, five (5) Regional Inspectorial 

Organisation (RIO) offices, each headed by an 

officer of the rank of Superintending Engineer 

function at New Delhi, Mumbai, Chennai, 

Kolkata and Shillong to inspect the HV/MV 

installations of the Central Government. 

B) Regional Power Survey Organisation 

(RPSO) 

Four (4) Regional Power Survey 

Organisation (RPSO) offices, each headed 

by an officer of the rank of Deputy Director 

function at New Delhi, Mumbai, Bangalore 

and Kolkata under Chief Engineer (DMLF) 

in the Planning Wing to carry out surveys 

to forecast the demand of power in their 

respective regions. 

C) Regional Power Committees (RPCs) 

Five (5) Regional Power Committees 

(RPCs) each headed by a Member Secretary, 

an officer of the rank of the Chief Engineer, 

are functioning at New Delhi, Mumbai, 

Bangalore, Kolkata and Shillong to facilitate 

the integrated operation of the Regional 

Electricity Grids. 

1.2 Functions of CEA 

The functions and duties of the Authority 

are delineated under section 73 of the Electricity 

“Honesty is the first chapter in the book of wisdom.” 

1


Act, 2003. Besides, CEA has to discharge 

various other functions as well under sections 3, 

8, 34, 53, 55 and 177 of the Act. 

Section 73 - Functions and Duties of the 

Authority 

a) advise the Central Government on 

the matters relating to the national 

electricity policy, formulate short-term 

and perspective plans for development of 

the electricity system and coordinate the 

activities of the planning agencies for the 

optimal utilization of resources to subserve 

the interests of the national economy and to 

provide reliable and affordable electricity 

to all consumers; 

b) specify the technical standards for 

construction of electrical plants, electric 

lines and connectivity to the grid; 

c) specify the safety requirements for 

construction, operation and maintenance 

of electrical plants and electric lines; 

d) specify the Grid Standards for operation 

and maintenance of transmission lines; 

e) specify the conditions for installation of 

meters for transmission and supply of 

electricity; 

f) promote and assist in the timely completion 

of schemes and projects for improving and 

augmenting the electricity system; 

g) promote measures for advancing the skills 

of persons engaged in electricity industry; 

h) advise Central Government on any matter 

on which its advice is sought or make 

recommendation to that Government 

on any matter if, in the opinion of the 

Authority, the recommendation would help 

in improving the generation, transmission, 

trading, distribution and utilization of 

electricity; 

i) collect and record the data concerning 

the generation, transmission, trading, 

distribution and utilization of electricity and 

carry out studies relating to cost, efficiency, 

competitiveness and such like matters; 

j) make public from time to time the 

information secured under this Act, and 

provide for the publication of reports and 

investigations; 

k) promote research in matters affecting the 

generation, transmission, distribution and 

trading of electricity; 

l) carry out, or cause to be carried out, any 

investigation for the purpose of generating 

or transmitting or distributing electricity; 

m) advise any State Government, licensees or 

the generating companies on such matters 

which shall enable them to operate and 

maintain the electricity system under their 

ownership or control in an improved manner 

and where necessary, in coordination with 

any other Government, licensee or the 

generating company owning or having the 

control of another electricity system; 

n) advise the Appropriate Government and the 

Appropriate Commission on all technical 

matters relating to generation, transmission 

and distribution of electricity; and 

o) discharge such other functions as may be 

provided under this Act. 

In addition to above functions and duties, CEA 

has to perform the following functions in terms 

of the under mentioned sections of the Electricity 

Act, 2003:- 

Section 3 - National Electricity Policy 

and Plan 

(1) The Central Government shall, from time 

to time, prepare the National Electricity 

Policy and Tariff Policy, in consultation 

with the State Governments and the 

Authority for development of the power 

2 “A person without a sense of humor is like a wagon without springs-jolted by every pebble in the road.”


system based on optimal utilization of 

resources such as coal, natural gas, nuclear 

substances or materials, hydro and 

renewable sources of energy. 

(2) The Central Government shall publish 

the National Electricity Policy and Tariff 

Policy from time to time. 

(3) The Central Government may, from time 

to time, in consultation with the State 

Governments and the Authority, review 

or revise the National Electricity Policy 

referred to in sub-section (1). 

(4) The Authority shall prepare a National 

Electricity Plan in accordance with the 

National Electricity Policy and notify such 

plan once in five years. 

PROVIDED that the Authority while preparing 

the National Electricity Plan shall publish 

the draft National Electricity Plan and invite 

suggestions and objections thereon from 

licensees, generating companies and the public 

within such time as may be prescribed; 

PROVIDED FURTHER that the Authority 

shall – 

a) notify the plan after obtaining the approval 

of the Central Government; 

b) revise the plan incorporating therein 

directions, if any, given by the Central 

Govt. while granting approval under 

clause (a). 

(5) The Authority may review or revise the 

National Electricity Plan in accordance 

with the National Electricity Policy. 

Section 8 - Hydro-electric Generation 

(1) Any generating company intending to 

set up a hydro-generating station shall 

prepare and submit to the Authority for its 

concurrence, a scheme estimated to involve 

a capital expenditure exceeding such sum, 

as may be fixed by the Central Government, 

from time to time, by notification. 

(2) The Authority shall, before concurring 

in any scheme submitted to it under subsection 

(1) have particular regard to, 

whether or not in its opinion: 

a) The proposed river-works will prejudice 

the prospects for the best ultimate 

development of the river or its tributaries 

for power generation, consistent with 

the requirements of drinking water, 

irrigation, navigation, flood-control, 

or other public purposes, and for this 

purpose the Authority shall satisfy 

itself, after consultation with the State 

Government, the Central Government, 

or such other agencies as it may deem 

appropriate, that an adequate study has 

been made of the optimum location of 

dams and other river-works; 

b) the proposed scheme meets, the norms 

regarding dam design and safety. 

(3) Where a multi-purpose scheme for the 

development of any river in any region is 

in operation, the State Government and the 

generating company shall co-ordinate their 

activities with the activities of the person 

responsible for such scheme in so far as 

they are inter-related. 

Section 34 - Grid Standards 

Every transmission licensee shall comply 

with such technical standards, of operation 

and maintenance of transmission lines, in 

accordance with the Grid Standards, as 

may be specified by the Authority. 

“If you employed study, thinking. and planning time daily, you could develop and use the power that can change the course of your destiny.” 

3


Section 53 - Provision Relating to Safety 

and Electricity Supply 

The Authority may, in consultation with the State 

Governments, specify suitable measures fora) 

protecting the public (including the person 

engaged in the generation, transmission 

or distribution or trading) from dangers 

arising from the generation, transmission 

or distribution or trading of electricity, or 

use of electricity supplied or installation, 

maintenance or use of any electric line of 

electrical plant ; 

b) eliminating or reducing the risks of 

personal injury to any person, or damage 

to property of any person or interference 

with use of such property; 

c) prohibiting the supply or transmission of 

electricity except by means of a system 

which conforms to the specification as 

may be specified; 

d) giving a notice in the specified form to the 

Appropriate Commission and the Electrical 

Inspector, of accidents and failures of 

supplies or transmission of electricity; 

e) keeping by a generating company or 

licensee the maps, plans and sections 

relating to supply or transmission of 

electricity; 

f) inspection of maps, plans and sections by 

any person authorized by it or by Electrical 

Inspector or by any person on payment of 

specified fee; 

g) specifying action to be taken in relation to 

any electric line or electrical plant, or any 

electrical appliance under the control of a 

consumer for the purpose of eliminating 

or reducing the risk of personal injury or 

damage to property or interference with its 

use. 

Section 55 - Use, etc. of Meters 

(2) For proper accounting and audit in the 

generation, transmission and distribution or 

trading of electricity, the Authority may direct 

the installation of meters, by a generating 

company or licensee at such stages of 

generation, transmission or distribution or 

trading of electricity and at such locations 

of generation, transmission or distribution or 

trading, as it may deem necessary. 

Section 177- Powers of Authority to Make 

Regulations 

1) The Authority may, by notification, make 

regulations consistent with this Act and the 

rules generally to carry out the provisions 

of this Act. 

2) In particular and without prejudice to the 

generality of the power conferred in subsection 

(1), such regulations may provide for 

all or any of the following matters, namely:- 

a) the Grid Standards under section 34; 

b) suitable measures relating to safety and 

electric supply under section 53; 

c) the installation and operation of meters 

under section 55; 

d) the rules of procedure for transaction 

of business under sub-section (9) of 

section 70; 

e) the technical standards for construction 

of electrical plants and electric lines and 

connectivity to the grid under clause (b) 

of section 73; 

f) the form and manner in which and the 

time at which the State Government and 

licensees shall furnish statistics, returns 

or other information under section 74; 

4 “Failing to plan is planning to fail.”


g) any other matter which is to be, or may 

be, specified; 

(3) All regulations made by the Authority 

under this Act shall be subject to the 

conditions of previous publication. 

1.3 Broad Functional Areas of work of 

Chairperson and the Members of the 

Authority 

Chairperson 

Chairperson is the Chief Executive of the 

Authority. 

Member (Planning) 

Formulation of National Electricity Plan; 

integrated resource planning; coordinating the 

activities of Planning agencies for optimization 

of resource utilization; formulation of short, 

medium and long term power plans; long and 

short term demand forecast and sensitivity 

studies; material and manpower planning; coal, 

oil and gas linkages to power projects; surveys 

for power demand growth; identification and 

testing of co-lateral parameters for economic 

model for demand forecasting; collection, 

compilation and publication of statistics of 

Power Sector; securitization of resources/ fuel 

availability and fuel efficiency with the support of 

emerging technologies; modernization of project 

management; concepts of skill development; 

pro-active technology forecasting approaches; 

research and development in Power Sector, 

co-ordination with multiple agencies involved 

in research and development activities, energy 

conservation; energy auditing; environmental 

aspects of thermal projects; coordination of fuel 

oil/ liquid fuel supplies; coal quantity and quality 

control; etc. 

Member (Thermal) 

Overall thermal power development in the 

country; updating, development and evaluation 

of thermal technologies; design and engineering 

of thermal projects; quality assurance standards 

and plans; preparation of model documents and 

standards; thermal projects investigation and 

ash utilization; monitoring of construction and 

stabilization of thermal projects and suggesting 

remedial measures to problems involved; 

renovation, modernisation and life extension 

programmes of thermal generating stations; 

making operating norms for thermal generating 

stations etc. 

Member (Hydro) 

Overall hydro power development in the 

country; technical appraisal of hydro-electric 

projects; integrated planning for utilization of 

water resources; assessment of hydro potential; 

assistance to States on investigation and project 

report preparation; construction & investigation, 

monitoring of hydro projects and suggesting 

remedial measures to problems involved; updating, 

development and evaluation of hydro technologies; 

environmental aspects of hydro projects; quality 

assurance plans and standardization, design 

and engineering of hydro projects; renovation, 

modernization and up rating of hydro stations; cooperation 

with neighbouring countries of Nepal, 

Bhutan and Myanmar for development of water 

resources for mutual benefits; etc. 

Member (Power System) 

Planning and development of Transmission 

system consistent with national power plans; studies 

for the purpose of appraisal of transmission projects; 

transmission technology development; design and 

engineering; standardization and preparation of 

model document; renovation and modernization 

of transmission schemes; construction monitoring 

of transmission projects; inspection of existing 

electrical installations in Union Territories and 

Central Gov ernment Departments; investigation of 

accidents on electrical installations and suggesting 

remedial measures for their minimization and 

prevention etc. 

“Let our advance worrying become advance thinking and planning.” 

5


Member (Grid Operation & Distribution) 

Formulation of policies for safe, 

secure and economic operation of regional 

grids; integrated operation, co-ordination of 

five regional grids through Regional Power 

Committees (RPCs); monitoring of delivery 

of shares from Central Sector projects; intra 

and inter-regional exchange of power; regional 

energy accounting; load generation balance; 

investigation of grid disturbances; matters 

relating Accelerated Power Development 

and Reforms Programme (APDRP) in J&K; 

monitoring of rural electrification programme; all 

matters relating to power development in union 

territories; telecommunication in Power Sector; 

telecommunication data acquisition and software 

support; operation monitoring and performance 

review of thermal power stations; updating 

of maintenance procedures; generation data 

collection; performance analysis; maintenance 

monitoring etc. 

Member (Economic & Commercial) 

Economic evaluation of power policies 

and projects; appraisal of tariff for Nuclear 

Power Stations; financial packages; financial 

parameters; interest during construction and 

completed cost; examination of bulk power 

tariff structure; performance of SEBs; scrutiny 

for import duty exemption; certification 

of deemed export benefit; co-ordination for 

externally aided schemes; examination of 

Power Purchase Agreements, advice on legal 

matters, etc. 

Secretary 

The Secretary (CEA) appointed by the 

Authority with the approval of the Government 

of India, assists the Authority in discharge of 

CEA’s statutory functions. The Secretary also 

assists the Chairperson (CEA) in all matters 

pertaining to administration and technical 

matters including human resource development 

and techno-economic appraisal and concurrence 

of hydro power projects, planning of budget and 

expenditure control etc. 

1.4 Personnel and Administration 

The staff strength of CEA as on 31.03.2009 

was 1146 against sanctioned strength of 1616 

leaving 470 posts vacant. Summarized position 

of staff strength is shown in the table below: 

Category Sanctioned Filled 

Head- 

Quarters 

Sub-Office Total Head- 

Quarters 

Sub- 

Office 

As on 31.3.2009 

Total 

Strength 

CPES GROUP-A 368 113 481 276 79 355 

CPES GROUP-B 92 17 109 42 9 51 

Non CPES Group 

Group -A 47 - 47 30 - 30 

Group -B 309 17 326 281 11 292 

Group -C 338 107 445 149 78 227 

Group -D 145 63 208 135 56 191 

Total 1299 317 1616 913 233 1146 

6 “In order to live free and happily you must sacrifice boredom. It is not always an easy sacrifice.”


1.4.1 Representation of women in CEA 

CEA had a total of 239 women employees as on 

31.03.2009. The group- wise number of women 

employees is shown in the table: 

Category No. of Govt. Employees No. of women employees % age 

Sanctioned Filled in position 

CPES GROUP-A 481 355 14 3.94 

CPES GROUP-B 109 51 10 19.60 

Non CPES GROUP 

Group A 47 30 5 16.66 

Group B 326 292 115 39.38 

Group C 445 227 81 35.68 

Group D 208 191 14 7.32 

Total 1616 1146 239 20.85 

1.4.2 Representation of Scheduled Caste 

(SC), Scheduled Tribes (ST), OBC & 

Physically Handicapped employees 

The group-wise number of Scheduled Caste 

(SC), Scheduled Tribes (ST), OBC & 

Physically Handicapped employees is shown in 

the table below: 

Category No. of Govt. Employees No. of SC 

Sanctioned Filled 

Govt. 

employees 

in position 

No. of ST 

Govt. 

employees 

in position 

No. of OBC 

Employees 

in position 

No. of 

Physically 

Handicapped 

Employees in 

position 

CPES Group-A 481 355 59 12 7 2 

CPES Group-B 109 51 2 - - 1 

Non CPES Group 

Group A 47 1 - - - 

Group B 326 39 11 1 3 

Group C 445 39 9 6 3 

Group D 208 191 68 4 5 1 

Total 1616 1146 208 36 19 10 

1.5 Representation of CEA Officers on 

Boards of PSUs 

The Chairperson, Members and other 

officers of CEA, who have been nominated to 

Board of Directors of various Public Sector 

Undertakings (PSUs) and other Government 

Organisations as technical experts, are shown 

in the table below: 

“Ambition should be made of sterner stuff.” 

7


Sl.No. Name & Designation of Officer Organisation Nominated as 

1. Sh. Rakesh Nath, Chairperson, CEA 

(w.e.f. 6.10.05) 

2. Sh. Gurdial Singh, Member (Hydro) 

(w.e.f. 02.12.04) 


(w.e.f. 02.12.04) 


(w.e.f. 02.12.04) 


(w.e.f. 02.12.04) 


(w.e.f. 24.01.2008) 

7. Sh. A.K.Gupta, CE (TRM) 

(w.e.f. 17.12.2007) 

8. Sh. A.K.Gupta, CE (TRM) 

(w.e.f. 12.12.2008) 

Nuclear Power Corp. Ltd. 

NEEPCO 

THDC 

SJVNL 

NHPC 

J&K State Power 

Development Corp. Ltd. 

Haryana Power Generation 

Corpn. Ltd. (HPGCL) 

West Bengal Power 

Development Corpn. Ltd. (WB- 

PDCL) 

Director 

Director 

Director 

Director 

Director 

Director 

Director 

Director 

1.6 Annual Budget 

During the year 2008-09, against an allocation 

of Rs.15.00 Crores (enhanced to Rs.15.44 

Crores in the RE 2008-09) under Plan head, 

an expenditure of Rs.9.05 Crores has been 

booked upto 31-03-2009. An expenditure of 

Rs.7.03 Crores was booked under Plan head 

during 2007-08. 

On the Non-Plan side during the year 

2008-09 an expenditure of Rs.58.79 Crores was 

incurred against an allocation of Rs.45.24 Crores, 

whereas during the year 2007-08, an expenditure 

of Rs.42.54 Crores was incurred. 

1.6.1 Revenue Recovered for Consultancy 

Services by CEA and Recovery of 

expenses by RPCs from constituents 

CEA renders Consultancy Services for 

design and engineering of thermal and hydro 

projects to various SEBs and power utilities. 

During 2008-09, CEA rendered consultancy 

services worth Rs.3.49 Crores and an amount of 

Rs.4.98 Crores was recovered during the year 

(upto 31-03-09). Regional Power Committees 

recovered revenue of Rs.8.16 Crores from their 

constituents during the year 2008-09. 

1.7 Progressive use of Hindi in Official 

Work of CEA 

All out efforts are being made to enhance 

the usage of Hindi in official work in CEA. 

All incentive schemes sponsored by the Deptt. 

of Official Language are in operation in CEA. 

In addition, a Roving Shield is awarded to the 

Division/Section/Unit who does maximum work 

in Hindi throughout the year. During the year, 

Rajbhasha Shields were awarded to 10 Divisions/ 

Sections where maximum correspondence 

is made in Hindi with Regions “A” & “B”. 

Apart from above CEA has introduced a Cash 

Award Scheme namely ‘Kendriya Vidyut Pustak 

Lekhan Puraskar Yojna’ on All India basis to 

promote original book writing in Hindi from the 

calendar year 2003. In pursuance of the Ministry 

of Power’s direction, prize money under this 

scheme has been increased to: First Prize - 

(A) Rs. 60,000/-, (B) Second Prize - Rs.40,000/- 

8 “The farther backward you can look, the farther forward you are likely to see.”


(C) Third Prize - Rs. 25,000/- and one consolation 

prize of Rs.10,000/- only. 

During the year four sub-offices of CEA 

i.e. in Calcutta, Bangalore, Mumbai and Shillong 

were inspected by the officers of CEA to assess 

the usage of Hindi in official work. During 

this year Parliament Committee has inspected 

three offices, namely CEA, and two sub-offices 

of CEA i.e. WRPC, Mumbai and NRPC, New 

Delhi. Official Language Implementation 

Committee’s quarterly meetings were held 

regularly. 

For the purpose of creating interest in 

Hindi, the Hindi Books were regularly purchased 

for library of CEA as per the target prescribed by 

the Official Language department. 

During the year, one Hindi Computer 

Training Programme was organized in 

coordination with NPTI, Faridabad in which 

about 25 employees have been trained in working 

on computers. Five workshops on Hindi were 

also organized in which about 105 employees 

have participated. 

Officers and employees were regularly 

nominated for Hindi Language, Hindi Typing and 

Hindi Stenography trainings conducted under 

the Hindi Teaching Scheme. In stenography, out 

of 153 employees 124 are trained, one is under 

training and 28 are still to be trained. In Hindi 

language, all officers/ employees of CEA are 

trained. 

1.8 Welfare Activities in CEA 

1.8.1 Activities undertaken for the benefit 

of the persons with Disabilities 

In order to provide both preventive 

and promotional aspects of rehabilitation 

– like education, employment/vocational 

training, job rehabilitation, research and 

manpower development, creation of barrier 

free environment, unemployment allowances, 

special insurance scheme and establishment of 

homes, for persons with disabilities etc., ‘The 

Persons with Disabilities (Equal Opportunities, 

Protection of Rights and Full Participation) Act, 

1995’ has been enacted. 

2. For providing opportunities in employment 

a 3% of vacancies in Government 

employment has been reserved for people 

with disabilities, 1% each for persons 

suffering from:- 

(i) 

blindness or low vision 

(ii) hearing impairment 

(iii) locomotor disabilities and cerebral 

palsy 

The representation of physically challenged 

employees in all categories of posts of CEA is 

given below:- 

Group 

Total Employees as 

on 31.3.2009 

Physically Challenged Employees 

VH HH OH Total 

Percentage of physically 

challenged employees 

A 385 1 1 2 0.56 

B 343 4 4 1.14 

C 227 3 3 1.26 

D 191 1 1 0.50 

Total 1146 1 1 8 10 0.87 

“It is always the best policy to tell the truth, unless, of course, you are an exceptionally good liar.” 

9


3. Since the building where CEA(HQ) is 

housed is not disabled friendly, the matter 

has been taken up with CPWD, who 

maintains the building for re-modeling/ 

making the building disabled-friendly, 

towards providing barrier-free environment 

in the office. Care is, however, taken to 

post such disabled persons, at disabledfriendly 

offices of CEA. 

4. The guidelines issued by Ministry of 

Social Justice & Empowerment and other 

Ministries/Departments in the matter are 

regularly forwarded for implementation 

to the Field Offices of CEA. The relevant 

returns about the implementation of the 

related programmes are sent to Ministry 

of Power for forwarding the same to the 

Office of Chief Commissioner for Persons 

with Disabilities, on regular basis. 

1.8.2.1 Benevolent Fund 

The Central Electricity Authority 

Benevolent Fund is a society registered under 

Societies Registration Act, 1860. The main 

objective of the Society is to provide financial 

assistance to the members of the Society on the 

following eventualities:- 

a. (i) When the member is prematurely 

retired due to sickness. 

(ii) When the member is on prolonged 

sickness leave. 

(iii) When the member suffers from 

any unforeseen misfortune. 

b. Providing financial assistance to member 

of families in case of death in service. 

The membership of the society is voluntary 

and open to all temporary and permanent 

employees of CEA located at New Delhi. The 

subscription is collected on monthly basis. The 

benefit of the fund is limited to those who are 

members of the society or their dependents 

namely widow, sons and daughters. Financial 

assistance to the extent of Rs. 2500/- (maximum) 

is given to the families of the deceased or to a 

member of the fund on medical grounds. 

1.8.2.2 Welfare of SC/ST/OBC 

Director (A-II) & Director (A-I) have been 

designated as Liaison Officers in CEA to look 

after the welfare of SC/ ST and OBC employees 

respectively. 

1.8.2.3 Activities related to women 

employees 

Women employees of CEA participated in 

activities such as sports, recreation & cultural 

activities. They have also been co-opted as 

members of CEA Departmental Canteen 

Management Committee, Culture activities 

Committee and Complaint Committee on sexual 

harassment of women at work place. 

1.8.3 Associations/ Unions in CEA 

The following Associations/ Unions 

of employees in CEA were active during 

2008-2009. 

(i) 

(ii) 

Power Engineers Association- Under 

process for recognition under CCS (RSA) 

Rules, 1993. 

Drawing Staff Association – Recognition 

extended for further period of three years 

under CCS (RSA) Rules, 1993. 

1.8.4 Pension Cases 

1.8.4.1 Pension Cases (Superannuation/ 

VRS including sanction of 

CGEGIS amount) 

48 regular superannuation cases, 4 VRS 

cases and 5 death cases have been settled during 

10 “The one exclusive sign of thorough knowledge is the power of teaching.”


the year 2008-2009 and necessary payment 

of retirement benefits have been released. In 

addition, 80 more revised pension cases were 

also settled subsequent to revision of Pay/ Pay 

Scale of PSs. 

1.8.4.2 Transfer of Capitalized value of 

Pensionary benefits 

Four cases of transfer of capitalized 

value in respect of ex-employees of CEA 

who have been permanently absorbed in 

Government Undertakings/Autonomous Bodies 

were processed and finalized where CEA has 

discharged its pensionary liabilities to the 

concerned Organisations. One case has been 

forwarded to PAO (CEA). 22 more such cases 

are under process. 

1.8.4.3 Restoration of one-third commuted 

portion of pension/ grant of 

Family Pension 

In terms of revised instructions/ guidelines 

issued by the Department of Pension & 

Pensioner’s Welfare calculation of 1/3 rd restored 

amount of commuted portion of pension vide 

O.M.No.4/79/2006-P&PW(D) dated 6.9.2007. 

Seven such cases relating to revision of the 

restored amounts of 1/3 rd portion of pension and 

their grant of family pension have been settled. 

1.8.4.4 Pro-rata pension (CAT/ Court Cases) 

17 cases of grant of pro-rata and other 

pensionary benefits to ex-employees of CEA 

permanently absorbed in PSUs who had 

approached the CAT/court for relief were 

processed. Out of these, 4 (four) cases where 

judgments were passed have been settled and 

requisite payments released as directed by the 

Hon’ble CAT/Court. In 2 (two) cases where 

judgments were received, the Department/ 

Government has filed “Appeal” in the Hon’ble 

Supreme Court and Delhi High Court. In 9 

(nine) cases, the judgments of the Hon’ble CAT 

required the Department to consider the claims 

of the applicant to pro-rata pensionary benefits 

and issue suitable orders. In these cases, 

the Department considered the claims of the 

applicants and finding them ineligible for pro-rata 

pensionary benefits, issued requisite speaking 

orders to them. The judgment received from the 

Hon’ble CAT in one case is under consideration 

of the Government. 3 (three) cases are still 

subjudice in the Hon’ble CAT/Court. 

1.9 Vigilance Activities / Disciplinary 

Cases in CEA 

The Vigilance Division, CEA deals with 

various facets of Vigilance mechanism and 

functions for carrying out investigations into 

complaints, suggesting corrective measures for 

improving the control system, compliance of 

laid down procedures and also for carrying out 

preventive vigilance exercises. 

Complaints other than anonymous/ 

pseudonymous were taken up for investigation 

promptly and after completion of investigation, 

reports submitted to the prescribed authority. As 

on 1.4.2008, there were five cases of disciplinary 

action pending under CEA’s disciplinary 

jurisdiction. One case was added during the 

period. All the six cases of disciplinary action 

have since been finalised. Thus, at present, 

(as on 31.03.2009) there is no case pending 

finalization. Prescribed periodical returns were 

sent to the Ministry of Power in time 

Vigilance Division has carried out 

inspection at one of the formations of CEA 

with a view to appraise and ensure adaptation 

of proper procedure as well as suggesting 

improvement thereon. As part of preventive 

vigilance, the Vigilance Division is helping in 

ensuring job rotation in sensitive posts. The 

Vigilance Division has also taken steps to 

“The doorstep to the temple of wisdom is the knowledge of our own ignorance.” 

11


ensure that web-site of CEA plays an important 

role in increasing transparency in its functions. 

Vigilance awareness week was observed from 

24 th Nov., 2008 to 28 th Nov., 2008 emphasizing 

the need for efficiency and transparency in public 

spending, raising awareness among the users of 

the services provided by the department, etc. 

1.10 Electric Power Information Society 

(EPIS) 

The Electric Power Information Society 

(EPIS) was established in June 1996 under the 

aegis of Central Electricity Authority on noloss-no-profit 

basis for bringing out various 

CEA publications. These publications including 

a quarterly technical journal “Vidyut Bharati” 

are being distributed by CEA among various 

Government agencies on complimentary basis. 

These are also available on sale for general 

public. 

During the year 2008-09, the following 

publications have been brought out: 

1. Vidyut Bharati, Quarterly Journal Issues 

(i) April - 2008 

(ii) July - 2008 

(iii) Oct. - 2008 

(iv) Jan. - 2009 

2. CEA Annual Report 2006-07 (Hindi 

Version) – July, 2007 

3. Performance Review of Thermal Power 

Stations, 2006-07 (Bilingual). 

4. Review of Performance of Hydro Power 

Stations, 2006-07. 

5. Electricity Tariff & Duty and Average 

Rates of Electricity Supply in India. 

6. All India Electricity Statistics (2006-07), 

General Review, 2008 – May, 2008. 

7. Guidelines for specifications of Energy 

Efficient Out Door Type Three Phase and 

Single Phase Distribution Transformers – 

Aug., 2008 

8. CEA Annual Report 2007-08 (English 

Version) – July, 2008 

1.11 Grievance Cell 

To redress the grievances of CEA Head 

Quarter, in accordance with the instructions of 

Deptt. of Administrative Reforms and Public 

Grievances, Shri S. K. Thakral, Chief Engineer 

(Electrical Inspectorate) is functioning as 

Director (Grievances). 6 cases were received 

during the period under review and 3 cases have 

been settled. Now, 9 cases are under process 

(including 6 nos. of cases received during 

previous year). 

1.12 Right to Information Act, 2005 

Under Right to Information Act 2005, Shri 

S. K. Thakral, Chief Engineer has been entrusted 

the work of Central Public Information Officer 

of CEA. During the financial year 2008-09, 90 

Nos. of requests/ applications were received 

and 93 Nos. have been decided including 7 Nos. 

of cases received before this period and 4 Nos. 

of cases are under process as on 31 st March 

2009. Six applicants had made Appeal to the 

First Appellate Authority/Central Information 

Commission, out of which 4 Nos. of cases have 

been disposed of at the level of First Appellate 

Authority and 2 Nos. of cases are under process 

in the Central Information Commission. 

1.13 Public Relations Group 

The Public Relations Group (PR Group) 

was constituted in CEA in March, 1999 with a 

12 “Children are our most valuable natural resource.”


view to consolidate and project the achievements 

of CEA as also to interact with the media. The 

PR Group is headed by Secretary, CEA. Shri 

R.K. Verma, Director (DP&D) who has been 

appointed as Director (PR), assists the Secretary, 

CEA in coordinating and implementing public 

relation activities with the help of officers from 

various wings. 

The Public Relation (PR) Group has been 

involved in the following activities:- 

• Preparation and issue of Press Releases 

covering all major CEA events. 

• Organising CEA stall in IITF Exhibition at 

Pragati Maidan, New Delhi. 

• Publication of brochure on CEA. 

1.14 Parliament Questions, Parliament 

Assurances, VIP references 

Work relating to answering of Parliament 

Questions, Parliamentary Assurances, VIP 

references, compilation and updating material for 

Consultative Committee and Standing Committee 

on Energy, compilation and processing of material 

for presentations such as power sector reform 

and private sector participation including action 

taken reports, notes for Estimates Committee 

and Ministers meeting on power scenario etc. 

were dealt with. This involved data sourcing 

and collection, preparation and forwarding of 

replies to MoP and participation in briefings. 

Subsequent need based queries and updating 

was also accomplished promptly. 

Material for ‘Calling Attention Motion’ 

and ‘No day Yet named Motions’ on various 

matters under Rule 196, 377 etc. of Parliament 

Procedure were also dealt with. 

Generation, compilation and updating 

of material in respect of various Consultative/ 

Standing Committee meetings were 

accomplished. The action taken reports on these 

were prepared with the help of data / replies 

received from various units. 

VIP / MoP references including references 

from PMO covering areas of Power Sector were 

processed and as a result of active communication 

with respective divisions/ authorities, data so 

generated was finalized and forwarded to MoP. 

Material was also compiled and processed for 

President’s Address to both the Houses of Parliament 

and Finance Minister’s Budget Speech. 

(A). During the year 2008-09, there were 4 

Parliament Sessions and the number of 

questions dealt with are shown in the table 

below:- 

(B) 

S.No. Particulars Starred Question Unstarred Question 

1 Budget Session 2008-09 37 234 

2 Monsoon Session 2008-09 19 89 

3 Winter Session 2008-09 19 101 

4 Interim Budget 2009-10 11 18 

During the year following references 

were dealt:- 

i) No. of Consultative 

Committees 

ii) No. of Standing 

Committees 

4 Nos. 

39 Nos. 

iii) VIP/PMO References (Non 

Administrative) 

iv) Calling Attention Motion, 

13 Nos 

No Day Yet Named Motion etc. 7 Nos. 

v) Assurances 10 Nos 


13


1.15 Monthly Reports 

CEA receives regular data on almost all 

the areas of Power Sector, such as generation, 

transmission and distribution of power. The 

information received is incorporated in the 

following regular monthly reports: 

• Report on important developments during 

the month for P.M.O. 

• Summary report for Council of Ministers 

on important developments in Power 

Sector during the month. 

• Executive Summary 

• Thrust area report for P.M.O. 

• Fortnightly Report for P.M.O. 

The first two reports are issued by 1 st and 5 th 

working day of every month briefly highlighting 

the major achievements/ milestones / critical 

issues in the Power Sector. 

The Executive Summary is issued by 10 th 

working day of every month and is an important 

reference document reflecting targets vis-àvis 

achievements in almost all the important 

areas of Power Sector in the month of review. 

Executive Summary of the important activities 

in the Power Sector is sent to Hon’ble Minister 

of Power and other concerned senior officers. 

The report contains the details of the thermal and 

hydro generating units commissioned during the 

month and the progress of major transmission 

lines & sub-stations commissioned. The status of 

generation vis-à-vis the programme and also the 

performance with reference to the corresponding 

period of previous years and the status of the 

coal position of various thermal power stations 

is highlighted. The up-to-date details of the 

generating capacity, energy demand and the 

demand met in various States and the Region are 

shown for overall review of the power situation 

in the country. 

1.15.1 Information on various issues 

provided to the Ministry of Power 

1. Material for Economic Survey 2008-09 

2. Material for IITF 2008 

3. ADB Energy Policy 2008-09 

4. Annual Report 2008-09 of M.O.P. 

5. Environment Statistics 2007-08 

6. Institution Mechanism for performance of 

PPP Projects. 

7. Major Achievements in Power Sector 

8. National Electricity Policy 

9. Study commissioned by ISCS on 

compensation to resource bearing states 

10. Rajiv Gandhi Gramin Vidyutikaran 

Yojana 

11. Citizen’s Charter of CEA for 2008-09 

12. Capacity addition. 

13. Issues relating to Transmission and 

Ditribution. 

1.16 Computerization in CEA 

The use of computers for power sector 

development was started in CEA in mid-sixties. 

In the initial years, the usage was mainly for power 

system planning studies. However, over the years 

computerization has pervaded all activities of 

CEA. A number of software packages have been 

procured (refer Software facilities) and in-house 

expertise developed. The hardware facilities 

have also been enhanced. 

All the technical Divisions and the administrative 

sections have been provided with computers to 



facilitate computerization of all the works in 

CEA. All the desktop computers in the offices of 

CEA located in Sewa Bhawan and West Block-II 

have been interconnected through wired as well 

as wireless LAN. The important statistics/data/ 

information of CEA is up-linked on the website 

of Central Electricity Authority (www.cea.nic. 

in) for global access. The bilingual (English & 

Hindi) website has been designed, developed 

and being maintained in-house by IT Division, 

CEA. The internet facility is provided to about 

600 officials through 34MBps RF link provided 

by NIC. 

1.16.1 Hardware Facilities 

The hardware facilities presently 

available include: 

• IBM X3800 Server (4 Nos.) 

• IBM X3500 Server (8 Nos.) 

• IBM P550 RISC Server (2 Nos.) 

• IBM DS4700 SAN storage, IBM make 

SAN switch, IBM TS3310 Tape library 

• Cisco Catalyst 4500 series core switch, 

Cisco Catalyst 3750 series L3 switch, Cisco 

2821 router, Cisco ASA5540 firewall. 

• About 600 Nos. of Pentium-III/Pentium- 

IV/Core 2 Duo based PC systems. 

• Advanced peripheral like A0 size plotters/ 

digitizers, colour laser printers, high speed 

digital printer-cum-copiers, A3 size inkjet 

printers, heavy duty line printers, CD 

writers, scanners, KVM (Keyboard Visualdisplay 

Management) Switch, etc. 

1.16.2 Software facilities 

The following system and application software 

are available: 

System software: 

• Redhat Enterprise Linux operating system 

• Windows Server 2003 enterprise edition 

• AIX operating system 

• Microsoft Windows XP/Vista operating 

system 

• Oracle Database 10g Enterprise edition, 

RAC, advanced security, Diagnostics 

pack, Tuning pack 

• IBM DB2 Content Manager Enterprise 

edition, performance expert 

• IBM Websphere application server, portal 

server, process server 

• Symantec antivirus enterprise edition 

• Lotus Domino enterprise mail server 

• Microsoft Windows CALS proxy 

software 

• Cisco LMS network management tool 

• IBM Tivoli storage manager 

• Cisco AAA software 

Application software: 

• Information Management Software for 

CEA 

• MS Office bilingual software. 

• Data Base-(Foxpro, Visual Dbase, MS 

Access) for desktop PCs 

• Report Generation (Adobe Acrobat 5/6) 

• Graphic Packages – (AutoCAD) 

• Microsoft Visual studio 

• Bilingual Software (LEAP, Akshar, APS 

2000++) 


15


• Payroll package for CEA (developed inhouse) 

• Office automation package for GPF/ 

Consultancy/ Billing/ Newspaper billing. 

Some of the important and scientific 

application packages available include: 

• Power System Analysis Package (PSAP) 

• Electric Generation Expansion Analysis 

System Model (EGEAS) 

• Integrated System Planning Model 

(ISPLAN) 

• MULTISYM. 

• River Basis Planning Module – 

SIMHYDE. 

• River Basis Planning Module – 

MINERVA. 

• Thermoflow software (GT Pro, GT Master 

and Peace, Steam Pro, Steam Master and 

Peace). 

• Caeser II Ver.4.5 standalone PC version- 

Pipe stress Analysis Software. 

• Cadworx-Plant design and Automation 

Software Version 2005 standalone PC 

Version 

• Autocad based specification driven Plant 

Design. 

• Primavera for enterprise for construction 

(P3ec) version 4.1. 

• AutoCAD 2005 – Standalone version. 

• STAAD Pro Structural Suite Software. 

• Cyme software for power flow study. 

• Software for Distribution Planning 

(SynerGEE). 

• PLS-CADD software package for 

transmission line terrain modeling. 

• i-tower software package for designing 

steel lattice structures. 

• Current Distribution Electromagnetic 

Interference, Grounding and Soil Analysis 

(CDEGS) software package. 

• PSCAD / EMTDC software package. 

• ASPEN one line for relay co-ordination. 

• ASPEN line constant programme. 

• CYMCAP package for ampacity 

calculation. 

• iSWITCHYARD software for design of 

switchyard and sub-station structures. 

• SIMPOW and NEPLAN – load flow, short 

circuit, optional power flow and stability 

studies. 

• PSS/E – for load flow, short circuit and 

stability studies. 

1.16.3 Usage of Facilities 

All the formations of CEA continue to 

make use of the existing computer facilities for 

carrying out studies and day-to-day work. The 

computer systems are extensively utilized by 

technical wings of CEA for bringing out various 

reports through complex engineering studies and 

analysis. These facilities are also used for internet 

communications, data transfer between CEA 

and MoP, budgetary allocation and monitoring 

and sanction/grant of loans/advances to CEA 

personnel. 

1.16.4 Upgradation of I.T. facilities in 

CEA 

Govt. of India, Ministry of Power has 

approved a scheme “Upgradation of I.T. 



facilities in CEA” at an estimated cost of Rs. 

9.52 Crores (revised cost estimate Rs.10.47 

Crores). The scheme under Phase-I envisages 

providing computers at each working desk, 

inter-connected through LAN and having the 

facility of Internet. The scheme envisages 

receiving data electronically from the Utilities 

online through CEA website by direct entry into 

the database. To achieve the above, the 14 Nos. of 

servers of various types along with firewall and 

intrusion detection system have been installed at 

Data Centre in Sewa Bhawan office building. 

This facility will provide CEA to create a 

centralized and online data base for analyzing and 

monitoring the data of Indian power sector. It would 

also facilitate (a) interlinking of various databases 

of different divisions of CEA on relational basis 

for sharing data among them, and (b) automatic 

uplinking of various data / information with CEA’s 

website. 

The work related to Data Centre and 

installation of servers and system softwares 

including establishment of LAN has been 

completed. Development of application software 

is in advanced stage of completion and is expected 

to be completed by June 2009. Entry of daily 

generation data into the IMS through Internet / CEA 

website has been started by a number of generating 

stations / companies of the country, for whom short 

training sessions for the purpose were arranged at 

CEA. The process of collection of nominations of 

the officers from different power sector entities viz. 

Generating companies, Transmission companies 

and Distribution Companies, who would be 

responsible for furnishing of daily / monthly / 

quarterly / half-yearly / annual information / data 

through Internet and would be imparted necessary 

training for the purpose, is in progress. 

The work on further upgradation of IT 

facilities in CEA in Phase-II has also been initiated 

with the following broad objectives: 

• To provide adequate redundancy in the 

existing data centre to enhance reliability 

of the system and to build a separate 

disaster recovery data centre. 

• More intensive and comprehensive IT 

based monitoring of execution of power 

projects. 

1.17 ISO 9001:2000 Quality System certification 

for CEA 

In order to improve the Quality of output 

and competency of the personnel of CEA, the 

Quality Management System (QMS) as per 

ISO 9001:2000 was adopted by CEA. Though 

ISO certification for all the wings of CEA was 

obtained from BIS during February-March 2004, 

a single composite license was obtained from 

BIS in 2007. Monthly, Quarterly and Half Yearly 

Review Meetings as prescribed in the Quality 

Manual on QMS are held in time in various 

divisions/wings at the level of Chief Engineers, 

Members and Chairperson (CEA). The BIS 

conducts Surveillance Audit once in a year for 

all wings for continuance of ISO certification. 

1.18 Resource Centre 

Resource Centre, a joint venture of CEA & 

BEE, was inaugurated by Secretary (Power) on 

28 th April, 2008. 

It is a state of the art, resource centre and is 

equipped with modern equipments: 

‣ Two (2) LCD screens for displaying the 

latest news/event hosted 

‣ One touch screen for searching books/ 

journals from the catalogue 


17


‣ One Wi-Fi for facilitating internet 

connection to thirteen (13) computers 

‣ Multi-purpose printer-Xerox facility 

connected with the computers 

Library management software ‘LIBCARE’ 

has been installed for tracking/ issuing/ returning 

books. The resource centre houses 10,000 books 

including 2000 in Hindi. Magazines/ Periodicals 

are displayed on the racks. 

Sitting arrangement, ambience and 

environment has been designed keeping in mind 

the need and comfort of the readers. 

1.19 Various Committees constituted by 

CEA 

The following committees/ working groups, 

comprising of CEA officers & others, were 

constituted by CEA: 

Sl. 

No. 

Date of 

constitution of 

Committee 

Name of the Committee 

1 06.05.2008 Committee of experts to review the Insulation requirement of EHV Transmission 

lines of various voltages. 

2 13.05.2008 Committee for identification of universities/institutions worldwide for conducting 

five professional/specialized training courses for CPES officers 

3 25.11.2008 Core Group in CEA for all matters relating to Power Sector development in North 

East Region 

Vindhyachal Super Thermal Power Station 3260 (6×210+4×500) MW in MP 

***** 



CHAPTER – 2 

PLANNING FOR POWER DEVELOPMENT 

2. Power Planning 

2.1.1 Generation Planning Studies 

(i) 

(ii) 

Generation Planning studies carried out 

for the terminal year of 12 th Plan and 13 th 

Plan for preparation of Draft National 

Electricity Plan. 

Power absorption studies for accord of 

concurrence to the following projects 

carried out: 

a) Singoli Bhatwari HEP (99 MW) in 

Uttarakhand by L&T Uttaranchal Hydro 

Power Limited 

b) Alaknanda HEP (300 MW) in 

Uttarakhand by GMR Energy Limited 

c) Rupsiabagar Khasiyabara HEP (261 

MW) in Uttarakhand by NTPC 

d) Gundia HEP(200 MW) in Karnataka by 

KPCL 

2.1.2 Reports on Power Planning 

1. An Expert Group was constituted under 

the Chairmanship of Member (Planning), 

CEA to examine and compile information 

available with various agencies for the 

Puga Geothermal fields, assess the 

geothermal potential and prepare an 

Action Plan for development of this 

potential. The data available with various 

agencies GSI, CEA, NGRI and NHPC 

who had been involved in exploratory 

studies over the last two decades was also 

collated and examined. The Report of the 

Expert Group was submitted to MNRE 

for implementation. 

2. Guidelines for qualifying requirement of 

bidders for Balance of Plants (BoP) of 

coal/lignite based thermal power project 

was finalized and circulated among PSUs 

and State Utilities in June, 2008 for 

consideration. Thereafter, based on the 

discussions held by the CEA Committee 

(comprising Chief Engineer, IRP & 

Chief Engineer, TE&TD as members), 

on the observations/ feed back received 

from EPC contractors, engineering & 

manufacturing firms, State Utilities 

& joint venture companies, certain 

modification in the guidelines is proposed 

to be carried out. 

3. Draft National Electricity Plan covering 

11 th Plan in detail and perspective 12 th and 

13 th Plan is under preparation. The draft 

plan will be circulated to all stakeholders 

for suggestions/comments and the same 

would be incorporated suitably in the final 

Plan. Thereafter, the Plan will be notified 

in the Gazette of India after approval of 

Government, as per the Electricity Act, 

2003. 

2.2 Participation as Committee Member/ 

Interaction Meets Organized/ 

Key Note Address delivered/ Paper 

Presented etc. 

1. As advised by the Chairperson, CEA, 

a Special Task Force on Bihar was 

constituted for preparing a vision paper 


19


on development of power sector in the 

state of Bihar. The same was prepared & 

submitted to Planning Commission. 

2. A visit was undertaken by CEA officers to 

BSEB’s headquarter in Patna to review the 

progress of action taken by BSEB/Govt. 

of Bihar on the recommendations made by 

Special Task Force on Bihar. 

3. Officers of CEA participated in the 

interactive session with captive power 

producers and industries held in Lucknow 

in December, 2008 in association with CII 

to know the progress on various fronts on 

the issues of captive generation and supply 

of surplus power to the grid/consumers. 

The interactive session was also attended 

by the representatives of State Utilities & 

SERC. 

2.3 Electricity Demand 

(a) 

Under existing system, electricity demand 

of the country is projected periodically, 

normally once in five years, for short and 

long time frames. The demand forecasting 

is done by a National level Committee of 

Experts constituted by CEA with consent 

of the Ministry of Power, by conducting an 

exhaustive Electric Power Survey of India. 

The demand forecast is basic input for 

formulation of National Electricity Policy, 

Developmental Plans and Programmes 

and Schemes concerning generation, 

transmission, trading, distribution and 

utilization of electricity. The demand 

forecast qualifies the need for development 

of various areas of electricity consumption 

to orient the growth of the specified sectors 

of development and leads to planned 

growth in various categories of electricity 

(b) 

consumption. Electric load forecast also 

drives the development of transmission 

highways and optimum transmission 

network for carrying electricity from 

generation centres to load centres. Interregional 

transmission links for electricity 

transmission from surplus region to deficit 

region is an important input for planning 

and development of such links. The 

load projections also facilitate planning 

of electricity transfer MoU and trading 

of electricity for the mutual benefits of 

surplus/deficit regions/States. 

The latest forecast of electricity demand 

had been made by the 17 th Electric Power 

Survey Committee and published in March, 

2007. The initiative for constitution of 18 th 

Electric Power Survey Committee has 

been taken. 

Analysis of Load Growth 

The 17 th EPS was prepared in consultation 

with utilities with various assumptions, in 

order to keep a watch on the load growth 

vis-à-vis demand forecast of various States. 

Regular analysis of energy demand and 

the peak demand is being carried out. The 

All India energy demand is very much in 

line with the 17 th EPS forecast i.e. Energy 

Requirement being 777 Bu against the 

projected forecast of 795 Bu for the year 

2008-09. The energy requirement of most 

of the Regions / States has deviated from 

projections in closed band of 0-5%. The 

peak demand projections on All India 

basis were about 10% more than the actual 

demand. The irregular increase in peak 

demand in some of the States without 

corresponding energy growth needs to 



be addressed through load management, 

Demand Side Management and T&D loss 

reduction programme. States have been 

advised accordingly. 

2.4 Publication on “Growth of Electricity 

Sector in India from 1947-2008” 

In fulfillment of its duties and functions 

stated under Section 73 (i) & (j) and exercising 

powers vested under Section 74 of the Electricity 

Act, 2003, CEA publishes documents carrying 

annual electricity statistics of National and 

International importance and growth indicators 

of the Indian Electricity Sector. A Publication 

titled “Growth of Electricity Sector in India from 

1947-2008” was brought out in May, 2008. The 

data for this publication has been sourced from 

various Utilities and Non-utilities and various 

National & International Journals. 

This annual publication of CEA illustrates 

the growth of vital development indicators like 

generating capacity, electrical energy production, 

transmission and distribution network, captive 

power plants and pattern of consumption of 

electricity etc. The important statistics have 

been compared with the International data with 

respect to some of the developed and developing 

nations. The booklet contains maps and charts 

presenting a panoramic view of the Indian 

Electricity Sector. 

2.5 General Review 

The “General Review” containing annual 

electrical energy statistics of utilities concerning 

growth of the Indian Electricity Sector. Important 

information like organizational structure of 

Electricity Supply Industry in India and reforms 

carried out by Utilities are incorporated. The 

General Review incorporates many important 

statistics/data on installed capacity, energy 

generation and utilization of energy along with 

the transmission and distribution losses. This 

publication contains energy utilization by various 

categories of electricity consumers like domestic, 

commercial, irrigation, industries (LV/MV, HV/ 

EHV), public lighting, public water works, etc. 

In addition, the information on captive generation 

by over 4500 HV/EHV industries is also compiled 

along with the installed generating capacity by 

captive generators. “General Review” – 2008 

containing data for the year 2006-07 has been 

published in May, 2008. 

2.6 Standing Committee on Derating, 

Uprating and Retirement of Installed 

Capacity of Stations 

The Authority had constituted a Standing 

Committee on Derating, Uprating & 

Retirement of Electricity Generating Units of 

Power Stations. The Committee evaluates the 

performance of the units through review of the 

technical performance vis-à-vis performance 

data and the overall generation throughout the 

life of the plant and after detailed scrutiny and 

visits to the various Power Stations and keeping 

in view the merits of the usefulness from case to 

case. The table below shows the units derated / 

retired during 2008-09 after scrutiny of their 

technical details. 

Consequent to the Report of Working 

Group III of National Mission of Enhanced 

Energy Efficiency (NMEEE) under National 

Action Plan on Climate Change (NAPCC), 

old and inefficient units proposed to be retired 

in the 11 th Plan totaling to a capacity of about 

3900 MW (900 MW already retired) have been 

identified. Matter will be taken up with the 

concerned agencies for the retirement of these 

units duly considering the new capacity addition 

in the respective States. 


21


2.7 Units Retired / Derated during 2008-09 

Sl. 

No. 

Name of Station/Plant 

Unit 

No. 

Installed 

Capacity 

(MW) 

Derated 

Capacity 

(MW) 

Net Deration 

Effect 

(MW) 

Retired 

(MW) 

1 Harduaganj T P S 2 50.00 0.00 0.00 50.00 

2 Harduaganj T P S 4 60.00 0.00 0.00 60.00 

3 Diesel Power Station(Chandigarh) 1To 5 2.00 0.00 0.00 2.00 

4 Amarkantak T P S 1 30.00 0.00 0.00 30.00 

5 Amarkantak T P S 2 30.00 0.00 0.00 30.00 

6 I PStation(Waste Heat Recovery) 7 34.00 30.00 4.00 0.00 



9 Obra T P S 3 50.00 0.00 0.00 50.00 

10 Obra T P S 4 50.00 0.00 0.00 50.00 

11 Obra T P S 5 50.00 0.00 0.00 50.00 

12 Faridabad T P S 2 60.00 0.00 0.00 60.00 

Total 484.00 90.00 12.00 382.00 

Net (Derated) (MW) 12.00 

Total (Retired) (MW) 382.00 

Grand Total 394.00 

2.8 Crisis & Disaster Management 

Subsequent to the publication of the Crisis 

& Disaster Management Plan for Power Sector by 

Ministry of Power in July, 2004 and the Disaster 

Management Act, 2005 as notified in the Gazette of 

India by the Ministry of Home Affairs, the National 

Disaster Management Policy is under finalization 

and the necessary inputs and suggestions in respect 

of Power Sector were provided to the National 

Disaster Management Authority. A note was 

prepared on vital installations in Power Sector for 

identification of increased security. 

Necessary inputs in regard to the Power 

Sector have also been provided to Ministry of 

Agriculture to arrive upon a Disaster Management 

Plan on drought management. 

2.9 Research & Development in Power 

Sector 

2.9.1 Perspective Plan for Research 

& Development 

A Standing Committee on R&D headed 

by Chairperson, CEA for preparation of a 

Perspective Research and Development Plan 

for next 15 years and to make recommendations 

from time to time for optimum utilization of 

infrastructure, raising of funds and to ensure that 

the outcome of research results in benefits to the 

customers and the operational efficiency of the 

sector, was constituted by the Ministry of Power 

in Feb. 2001. 

The Standing Committee recommended 

eight R&D projects to Ministry of Power for 



allocation of funds. Four of these projects where 

the beneficiaries of the projects were contributing 

towards the cost of the project have been taken 

up for R&D. 

The seven Task Forces which were 

constituted to assist the Standing Committee 

on R&D (SCRD) has been entrusted with 

identification of the areas of R&D as well 

the specific R&D projects to be taken up 

during 11 th Plan period in their respective 

fields. The Task Forces are also to guide 

formulation of project proposals in the 

identified R&D areas. The Convenors of the 

Task Forces are enthused with monitoring 

the progress of ongoing R&D Projects. The 

status of ongoing R&D projects is detailed 

in Annexure-2A. 

Most of the task forces have convened 

their meetings several times and have examined 

project proposals received by them. More than 

40 R&D project reports submitted by R&D 

organisations to the task forces have been under 

examination by them, that can be taken up during 

the 11 th Plan period. 

The 12 th meeting of Standing Committee on 

R&D was convened by Chairperson, CEA 

on 18 th February, 2009. The committee in its 

meeting recommended 12 projects to be taken 

up initially for R&D during the 11 th Plan period. 

In this regard, an SFC Memo is being prepared 

for submission to MoP for allocation of funds. 

The details of these projects are: 

Sl.No R&D Project Lead Agency 

1 Development of Silt Erosion Resistant Nano-composite 

coatings by Physical Vapour Deposition for Hydro 

Turbine Components 

IIT – Roorkee 

2 Tunneling in water charged zones under high 

hydrostatic pressure 

NHPC 

3 Design and Development of HTS Fault Current Limiter Compton Greaves Ltd 

4 Development of DVR based voltage source stabilizers for 

process industry 

C-DAC, Thiruvananthapuram 

5 Power Quality Harmonic Analysis on Grid Substation Feeders 

in NDPL Network’ 

NDPL, New Delhi 

6 RLA studies for Substations NDPL, New Delhi 

7 Developing of Metering Protocol Test Suite CPRI, Bangalore 

8 Implementation of Wide Area Measurement System (WAMS) in 

MSETCL grid’ 

MSETCL, Mumbai 

9 Improvement in reliability, safety and long term Performance 

of Power & converter transformers through improvements in 

quality of transformer Oil 

CPRI, Bangalore 

10 Environment friendly Flame retardant Nano composites for low 

and medium Voltage Cable Insulation applications 


11 A study on Stability and Reliability of the Power System with 

Large penetration of Wind Power 


12 Integrated sustainable power generation from short rotation 

forestry ‘enhanced bio-mass’ in rural and semi urban areas 

within CDM (Co 2 

mitigation) 

IIT Delhi 


23


2.9.2 Innovative R&D Proposals 

Work regarding promotion of innovative 

methods of electricity generation continued and 

12 Nos. of proposals received, from individuals 

through MoP, PMO, President Secretariat, were 

examined and commented upon. 

2.9.3 R&D works relating to Hydro Power 

Generation 

The various R&D schemes/projects to 

be taken up in the Hydro Sector during 12 th 

Plan were examined and feasible projects were 

identified in consultation with the Members of 

the Task Force represented by BHEL, NHPC, 

NML, IIT Roorkee, CPRI etc. 

The various R&D schemes which were 

under different stages of examination are 

indicated as under. 

i) Silt Erosion Nanocomposite Coatings by 

Physical Vapour Deposition for Hydro 

Turbine Components from Dr. Ramesh 

Chandra, Associate Professor, I.I.T 

Roorkee. 

ii) 

iii) 

iv) 

Design & Development of Silt Erosion 

Resistant Hydro Turbine Components 

from Dr. D.K.Diwedi, Asstt. Professor, 

I.I.T Roorkee. 

Development of Erosion Resistant Duplex 

Stainless Steel for use in hydro power plant 

from Dr. G.P.Chaudhary, I.I.T Roorkee. 

Evaluation of efficacy of rock reinforcement 

measures on long-term stabilization of 

hydel caverns from CIMFR, Nagpur. 

v) Development of models for design of 

road header specification and performance 

prediction in different geological conditions 

using laboratory and in situ dynamic rock 

mass properties for rapid tunneling from 

CIMFR, Nagpur. 

vi) 

vii) 

Impact of blast-induced dynamic loading 

on the long-term stability of large sized 

hydro-cavern from CIMFR, Nagpur. 

Selection of Optimum Sites for Hydro Power 

Generation using Geospatial Techniques 

from Dr. R.D. Garg, IIT Roorkee. 

viii) Predicting geology and classifying rock 

mass for support design ahead of tunnel 

face from CIMFR, Roorkee. 

ix) 

Tunneling in rock burst prone areas from 

CIMFR, Roorkee. 

x) Assessment of correlation between Rock 

types and tunneling rate in Himalayas 

from CIMFR, Roorkee. 

xi) 

Ecological study of Hydro reservoirs for 

estimation of Green House Gas Emission 

from NHPC. 

xii) Flow through downstream of Dam and 

Barrage for sustaining aquatic life & other 

requirements from NHPC. 

xiii) Methods for accurate assessment of 

underground geology upto 3 kms from 

NHPC. 

xiv) Compilation of data and correlation 

between categories of rocks in Himalayan 

geology and excavation rates of tunnels in 

various hydro projects from NHPC. 

xv) 

Tunneling in water charged zones under 

high hydrostatic pressure from NHPC. 

xvi) Design and development of a DSP based 

controller for small hydro and wind 

power generation from Dr. S.P. Singh, IIT 

Roorkee. 

2.10 Preparation of Database 

The data/information regarding R&D 

work in power sector being carried out by 

various agencies/organizations in Private and 



Government Sectors in India was obtained 

and compiled in the form of a Directory and is 

available on CEA Website. The Directory has 

been updated based on the revised information 

obtained from various Research Organizations. 

2.11 CEA Chairs at Indian Institute of 

Technology, Delhi 

An MOU exists between CEA and the 

Indian Institute of Technology, Delhi for 

creation of two CEA Chair Professorships, one 

in the Center for Energy Studies alternatively 

Department of Mechanical Engineering and the 

other in Electrical Engineering Department, to 

fulfill following objectives concerning Power 

Sector. 

• To take part in the academic programs of 

IIT, Delhi, as full time professors/faculty in 

the Center for Energy Studies alternatively 

Department of Mechanical Engineering 

and Electrical Engineering Department and 

coordinate HRD programs in the frontier 

areas of Power Management. 

• To develop R&D programs relevant to 

the needs of CEA and in areas defined in 

the appendix to the MOU (subject to need 

based revision.) 

• To initiate and develop HRD programs 

relevant to the needs of CEA and to 

coordinate courses for any batch of students 

from the CEA. 

Under the programme, a number of topics for 

research have been forwarded to IIT, Delhi. 

A total number of 8 officers of CEA, 

Ministry of Power and NPTI are pursuing 

M..Tech. and PhD courses at IIT, Delhi under the 

chairs. This would accrue benefits to the Power 

Sector in long run. Till date 8 No. of officers 

have completed M. Tech from IIT Delhi. 

2.12 Energy Conservation 

2.12.1 Indo-German Energy Efficiency 

Programme 

A project “Power Plant Optimization 

Component: Improvement in the availability 

and efficiency of Power Plants” under Indo 

–German Efficiency programme (IGEN) is 

being implemented jointly by M/s GTZ and CEA 

with the objective to promote energy efficiency 

and its conservation through improvement in 

the availability and efficiency of Power Plants. 

Implementation agreement between Ministry of 

Power and M/s GTZ was signed in November 

2006. The following are the outcome expected 

of the scheme: 

1. Improved availability and efficiency of 

thermal power plants 

2. Establishment of mapped power plants 

data bank in CEA 

3. Report of Energy conservation impact in 

power plants 

4. Establishment of Energy Efficiency cell at 

Power Plants 

5. Training to the power plant professional 

on power plant optimization 

6. Standard Prescribed format for submitting 

Energy Audit Reports 

7. Organization of Dissemination Seminars. 

Under the programme, the work of mapping 

of 85 units at 47 nos. Thermal Power Stations all 

over the country has been completed in association 

with GTZ.Units of 100/200/210/250/500 MW at 

different stations of various state utilities/Power 

Producing Cos. have been covered. All TPSs in 

the country have been advised to set up Energy 


25


Efficiency Cell and appoint Energy Manager in 

compliance to the EC Act – 2001 and about 69 

stations have so far reported the establishment of 

cell & its structure. 

The mapping reports prepared for various 

Thermal Power Stations of MAHAGENCO, 

GSECL, APGENCO & TNEB were discussed 

with management and senior officers from 

the concerned stations for implementation of 

the recommendations and on modalities for 

adoption of advance efficiency improvement 

technologies. 

A high level delegation comprising 

Shri Rakesh Nath, Chairperson, CEA, Shri 

V.S. Verma, Member (Planning), CEA and Shri 

Girish Pradhan, Additional Secretary, MoP was 

deputed by Ministry of Power, Government of 

India to visit Germany during 14 th -19 th July, 

2008 to review the progress of the projects under 

implementation and plan for new initiative 

under the Programme. The delegation was 

also accompanied by Mr. Jens Burgtorf, IGEN 

Manager in India from GTZ and Dr. J.T. 

Verghese, Managing Director, Evonik Energy 

Services, India. The visit was planned to get a 

first-hand impression of the latest technologies 

being adopted in German Power Plants to 

enhance efficiency and reliability which can have 

application in India. Discussions were also held 

with top level management and engineers of the 

companies and institutions in order to formulate 

the strategy to be implemented in India. 

The high level delegation suggested to the 

German side that the following activities may 

be taken up for consideration under the Indo- 

German Energy Forum:- 

i) Setting up of Excellence Enhancement 

Centre in CEA in association with VGB. 

ii) 

Provision of Ebsilon software tool for 

iii) 

the State utilities along with necessary 

training. 

Showcasing at least one power station out 

of the stations mapped in each utility where 

the combination of German and Indian 

experts would provide guidance in order 

to achieve higher efficiency and reliability 

without capital expenditure. 

iv) Support and installation of online 

optimization system for thermal 

efficiency. 

v) Pilot project on stress wave analysis 

technology for fault detections in power 

plant. 

vi) 

Programme to be chalked out to enable the 

visit of engineers from CEA and design 

and operation of Indian power plants to 

German Power Plants for training and 

familiarization for maximum efficiency 

operation of power plants. German side 

had agreed for this. 

vii) Possibilities of entering into a standing 

arrangement/MOU with M/s. Evonik 

Energy Services through GTZ for keeping 

update on the high technological areas 

of power sector and other developments 

could be explored. 

To introduce the more efficient operation of 

TPS, an interactive workshop/Seminar, on “Best 

Practices in Thermal Power Plants & launching 

the Model Power Plant Concept”, was held on 

30 th Jan., 2009 at New Delhi. Three documents- 

(i) Concept paper on establishing Model Power 

Plants (ii) Guidelines for Energy Auditing of 

TPPs (iii) Compendium of Best Practices for 

Efficient Operation of TPPs were also released 

by Member (Power), Planning Commission. The 

seminar/workshop was attended by various power 



producing companies of different sectors in the 

country, power plant equipment manufacturers 

and other associated dignitaries. 

Documents on “Guidelines for Energy 

Audit at Thermal Power Stations” and “Manual 

for Best Practices on Power Plant Operation” are 

being circulated among various mapped thermal 

power stations and power producing companies 

for seeking their comments/observations. 

A workshop/seminar in association with 

VGB was held on 13 th February, 2009 in New 

Delhi to workout the modalities for setting up 

of Excellence Enhancement Centre in CEA as 

recommended by high level delegation which 

visited Germany. 

Programme of visit of 50 power plant 

operation engineers/officials from various 

thermal power stations in the country, MoP 

and CEA to German Power Plants for training 

and familiarization for maximum efficiency 

operation of power plants was finalised. Two 

batches of total 20 engineers have already 

visited Germany in the month of March, 2009 

and visits of 30 engineers/officials are being 

arranged. 

2.12.2 Clean Development Mechanism 

The Clean Development Mechanism 

(CDM) under Kyoto protocol to the United 

Nations Framework Convention on Climate 

Change (UNFCCC) provides an opportunity for 

the Indian Power Sector to earn revenue through 

the reduction of Greenhouse Gases emissions 

particularly Carbon Dioxide (CO 2 

). 

Accordingly Central Electricity Authority 

(CEA), took up in cooperation with GTZ-CDM 

India, compiled a CO 2 

database for all gridconnected 

power stations in the country. The 

objective of the database is to facilitate the 

consistent and accurate quantification of CO 2 

emissions baseline by CDM project developers 

in the Indian power sector. India is the first 

CDM country in the world to have published 

such an official baseline for the power sector 

in the country as a whole. The database along 

with a User’s Guide is available on CEA website 

www.cea.nic.in. The latest version 4.0 contains 

the data upto 2007-08. CEA has also worked 

out CO 2 

base line emission factor as per CDM 

approved methodology ACM 0013 for the new 

upcoming super critical coal based power plants 

for availing CDM benefits. 

2.12.3 Asia Pacific Partnership (APP) - 

introducing Best Practices for 

Efficiecy Improvement in 

Power Plants. 

Asia Pacific Partnership (APP) on Clean 

Development and Climate is an innovative 

new effort to accelerate the development and 

deployment of clean energy technologies with 

founding members from Australia, China, India, 

Japan, Korea and USA. 

The United States Department of 

Energy’s (USDOE) Office of Fossil Energy 

and NETL is taking the lead in implementing 

activities targeted at improving the efficiency 

of coal fired power plants in India under 

Asia Pacific Partnership (APP) Program on 

Clean Development and Climate. Under APP 

program, a task force on Power Generation and 

Transmission has been formed with an objective 

to facilitate demonstration and deployment of 

practices, technologies and processes to improve 

efficiency of the power generation. 

Under the APP Program, NETL would 

provide all the technical expertise, heat rate 

improvement guidelines and other technical data 

assessment tools, training and demonstration 

etc. for few State Electricity Boards/Generation 


27


Companies to give exposure of best practices, 

techniques. 

Ropar Thermal Power Station of Punjab 

State Electricity Board and Kolaghat Thermal 

Power Station of WBPDCL have been shortlisted 

to carry out studies. 

Draft report on studies carried out at Ropar 

TPS and Kolaghat TPS have been submitted by 

consultant in the month of March, 2009. The 

report is being examined by the respective station 

authorities. It is proposed to formulate action 

plan on implementation of recommendations by 

respective thermal power stations. 

USAID along with CEA has taken up a 

study of ESP performance at one unit of Tuticorin 

Thermal Power Station. Unit 2 of 210 MW 

was selected for carrying out ESP performance 

studies. 

Design and actual data in respect of unit#2 

ESPs were collected by the experts. Some of the 

options that will be looked into are: (a) Alignment 

of plates (b) operational adjustments (c) gas 

distribution correction (d) performance related 

maintenance (e) improved AVC controllers (f) 

modifications to rapping system. Consultant has 

submitted its report to Tuticorin TPS authorities. 

It is proposed to take up boiler optimization 

studies at Tuticorin TPS. The work on the same 

is expected to start soon. 

2.12.4 Environment aspects of electricity 

generation 

CEA collected and compiled the monthly 

environmental related data for the year 2008-09 

for thermal power stations that are in operation. 

Those power stations where stack emissions 

exceeded the norms were addressed to take 

remedial measures and draw up action plan so 

that such emissions are brought down within the 

prescribed norms. 

2.13 Demand Side Management 

2.13.1 National Energy Conservation 

Awards, 2008 

Ministry of Power had undertaken a 

scheme to encourage, motivate as well as 

give recognition through National Energy 

Conservation Awards to industrial units and other 

establishments, who have taken extra efforts 

to reduce energy intensities while maintaining 

the production levels. The scheme is aimed to 

create an environment that would spur industries 

and other establishment in achieving excellence 

in efficient use of energy and its conservation. 

The awards were given away for the first time in 

December, 14, 1991 which is now celebrated as 

National Energy Conservation Day throughout 

the country. Chief Engineer (C&E), CEA was a 

member of Technical Sub-Committee to assist the 

Award Committee in the finalization of awards. 

During the year 2008, 49 proposals received 

from three industrial sectors viz. Dairy, Chlor- 

Alkali and Fertiliser sectors were evaluated by 

CEA. 

2.13.2 Comprehensive Award Scheme for 

Power Sector 

With a view to ensuring optimum 

availability of generating units during daily peak 

period and to encourage thermal power stations 

to undertake planned maintenance of their units, 

a scheme for Meritorious Productivity Award 

was first conceived in 1983 when Plant Load 

Factors of utilities thermal power stations were 

around 50%. This Scheme was further reviewed 

and revised in 1992-93 and new schemes for 

Incentive Award for Efficient & Economic 

Operation of Thermal Power Stations for reducing 

their Specific Secondary Fuel Oil Consumption 

as also Auxiliary Power Consumption were also 

introduced. 



These award schemes have shown 

encouraging results. Thermal Power Stations 

have considerably improved their performance 

and All India Average PLF of power stations has 

increased to the level of 74.8% in 2004-05 which 

has now further increased to 78.6% during the 

year 2007-08. 

There has been improvement in the field 

of Secondary Fuel Oil Consumption and also in 

Auxiliary Power Consumption due to concerted 

efforts of O&M personnel of thermal power 

stations. It was also considered desirable to 

extend the scheme to cover all important & 

relevant areas of power sector such as hydro 

projects, transmission projects, distribution 

companies, nuclear projects and other new areas 

of importance related to power sector such as, 

early completion of projects. New awards for 

meritorious performance in Rural Distribution 

Franchisees was included from 2007-08 

onwards. 

• A Comprehensive Award scheme to institute 

the following awards in the various areas 

of power sector was prepared by CEA and 

approved by Ministry of Power: 

• Th-1: Thermal Power Station Performance 

Awards. 

• Th-2: Early Completion of Thermal Power 

Project Awards. 

• Hy-1: Hydro Power Station Performance 

Awards. 

• Hy-2: Early Completion of Hydro Power 

Project Awards. 

• Tr-1: Transmission System Availability 

Awards. 

• Tr-2: Early Completion of Transmission 

Power Project Awards. 

• Nu-1: Nuclear Power Station Generation 

Award. 

• Rf-1: Performance Award for distribution 

companies. 

• Rf-2: Performance Award for Rural 

Distribution Franchisees. 

All stations/projects of Central, State, 

Private Sector (excluding Captive Power Plants) 

are eligible to compete for the awards under this 

scheme and the evaluation of performance shall 

relate to the financial year i.e. from 1 st April to 

31 st March. Selected stations/projects shall be 

awarded suitably and there shall be no cash 

awards. 

2.13.3 Awards for the year 2007-08 

Based upon the data/inputs furnished 

by various power utilities, the national awards 

for power utilities for meritorious performance 

during 2007-08 were distributed by Her 

Excellency Hon’ble President of India, Smt. 

Pratibha Devisingh Patil and Sh Sushil Kumar 

Shinde, Hon’ble Minister of Power during a 

function held on 17.02.2009. The list of awardees 

is given at Annexure-2B. 

This scheme is a part of the “Comprehensive 

Award Scheme for Meritorious Performance 

in Power Sector”. Performance Award Scheme 

for thermal power stations has been developed 

with a view to accord recognition to power 

stations based on their all-round performance by 

integrating the four operational parameters viz. 

Station Heat Rate, Auxiliary Power Consumption, 

Specific Secondary Fuel Oil Consumption and 

Peaking PLF. The scheme in its present form is 

intended to foster the competitive spirit amongst 

various power stations so as to encourage them 

to improve performance in all spheres of their 

working. The scheme would also help in evolving 


29


bench mark for various performance indices. 

The scheme covers all coal/lignite based and 

Combined Cycle Gas Turbine (CCGT) thermal 

power stations of Central, State and Private 

Sector (excluding captive power plants) having 

units of size 100 MW or above for coal based 

power stations whereas CCGT based power 

stations should have at least one GT of size 30 

MW or above. The award scheme envisaged six 

awards for meritorious performance of thermal 

power stations. 

During the year 2007-08 six top ranked 

thermal power stations were given awards based 

on the performance of their four operational 

parameters. It is worthwhile to mention that these 

award-winning stations have achieved Peaking 

PLF to the tune of 91.2% to 98.06% during the 

year. Award winning stations are listed below: 

Sl.No. Name of TPS Organisation Award 

1 Talchar STPS (3000 MW) NTPC Ltd. Gold Shield 

2 Korba STPS (2100 MW) NTPC Ltd. Silver Shield 

3 Ramagundam STPS (2600 MW) NTPC Ltd. Silver Shield 

4 Dadri TPS (840 MW) NTPC Ltd. Bronze Shield 

5 Rihand STPS (2000 MW) NTPC Ltd. Bronze Shield 

6 Torangalu TPS (260 MW) JSW Energy Bronze Shield 

2.13.4 Working Group-III for Natioal 

Action Plan on Climate Change 

(NAPCC) 

iii) 

Clean Coal Technology, Supercritical/ 

Ultra supercritical, Integrated Gasification 

Combined Cycle. 

Ministry of Power constituted a Working 

Group-III with Member (Plg.), CEA as the 

Chairman for preparing a detailed implementation 

action programme in respect of Technical Issues 

under the National Mission on Enhanced Energy 

Efficiency (NMEEE) under the National Action 

Plan on Climate Change in September, 2008. 

The Working Group in its three meetings 

held in September to November, 2008 deliberated 

on the various issues involved and prepared a 

report containing the recommendations stated 

hereunder. The report was submitted to Ministry 

of Power in December, 2008. 

i) Efficiency Integrated R&M / LE 

Programme for existing TPSs. 

iv) 

Development of materials for supercritical 

/ ultra supercritical parameters. Formation 

of separate sub-group consisting of Boiler 

/ TG manufacturer and steel manufacturer 

for in depth deliberation on the subject was 

recommended. 

v) Working Group also made recommendation 

on some other related issues like coal bed 

methane associated with coal reserves, 

fuel switching possibilities, setting up 

combined cycle plants on natural gas etc. 

2.14 Fuel Management and Analysis 

2.14.1 Standing Linkage Committee 

(Short-Term) 

ii) 

Criteria for Retirement of very old and 

inefficient units. 

Commitment to supply coal to new power 

projects is granted by Ministry of Coal based on 



the recommendations of the Standing Linkage 

Committee (Long Term) on the basis of normative 

parameters. After commissioning of the project, 

long term linkages are transformed into short term 

linkages based on actual requirements. Allocation 

on quarterly basis are made by the Standing 

Linkage Committee (Short term) [SLC (ST)], 

headed by an Additional Secretary in the Ministry 

of Coal, having representatives from the Ministry 

of Power, Ministry of Railways, Coal India Ltd. 

and Central Electricity Authority. For each quarter, 

the demand for allocation of coal was discussed 

with the respective power utilities in Pre-SLC (ST) 

meetings convened by Central Electricity Authority 

under the Chairmanship of Member (Planning), 

CEA, to assess the realistic coal requirement of 

individual power stations in the country, along with 

the proposed linked sources and was recommended 

to Ministry of coal for consideration in the SLC 

(ST) meetings. The assessment for coal requirement 

was made on the basis of generation targets for the 

period under consideration, current PLF, PLF for 

the same quarter during previous year, station-wise 

actual Specific Coal Consumption, maintenance 

schedule of units and new units expected to be 

commissioned. The norms of coal stock building 

vis-à-vis willingness of the SEB’s/ Utilities to 

maintain coal stock were also considered. While 

allocating the coal source-wise, rough estimates 

were carried out to assess the percentage of ash 

component for 36 TPSs covered under MoE&F 

Notification to ensure that the annualized average 

content of ash in the coal supplied was less than 

34%. Quantities of the imported coal assessed to 

be utilized by different thermal power stations 

during the quarter were also considered while 

recommending their coal requirement. 

2.14.2 Monitoring of Coal Supply to 

Power Stations 

The coal supply to 78 utility thermal power 

stations of the country (16 pit-head and 62 rail 

fed, having total installed capacity of 69025.5 

MW) and their coal stocks was vigorously 

monitored in Central Electricity Authority on 

daily basis, based on the quarterly allocation 

made by SLC(ST). 

Coal stocking norms for power stations 

were fixed by a Committee headed by Secretary, 

Planning Commission as 15 days for pit head and 

non-pit head varying from 20 days to 30 days 

depending on the distance of the power plant 

from the pit-head as per details given below: 

• Pit-head Station -15 days 

• Upto 500 Kms. away from Coal 

mine-20 days 

• Upto 1000 Kms. away from Coal 

mine-25 days 

• Beyond 1000 Kms. away from Coal 

mine- 30 days 

All India coal stock required at the 78 

coal based power stations monitored by CEA 

based on norms given above is of the order of 22 

Million Tonnes. However, under cash and carry 

scheme for supply and transportation of coal, as 

also due to inadequate stocking space, some of 

the power stations/utilities were not able to keep 

high inventory, in view of liquidity problem. 

The stations having coal stock for less than 

7 days are classified as ‘Critical’ and those having 

coal stock for less than 4 days are classified as 

‘Super Critical’. Efforts are made at all levels 

in CEA, Min. of Power, Min. of Coal, Coal 

Companies and Railways to bring such stations 

out of criticality. 

The monitoring involved collection of 

information on day-to-day basis from various 

TPSs/Utilities, preparation of daily coal stock 


31


report, overseeing of movement of coal as per 

linkage and intervening whenever deviation 

occurred, collection of the information regarding 

quantity and quality of coal supplied to power 

stations etc. 

The Infrastructure Constraints Review 

Committee, headed by Secretary (Co-ordination) 

in the Cabinet Secretariat, review the coal 

production and supply to thermal power stations 

in the country almost every month. 

A Sub-group of the Infrastructure 

Constraints Review Committee headed by an 

Additional Secretary in the Ministry of Coal, 

consisting of the representatives from the Ministry 

of Power, Central Electricity Authority, Ministry 

of Railways and Coal India Ltd., in its weekly 

meetings reviewed and resolved the problems 

of coal supply to thermal power stations having 

coal stocks below 7 days requirement. 

2.14.3 Coal Supply Position during 

2008-09 

Due to heavy monsoon in the coal mining 

areas followed by law and order problems, 

production of coal and hence its supply to power 

stations was badly affected. All India coal stock 

at power stations got depleted from 11 Million 

Tonnes (MT) to an alarmingly low level of 4.7 

MT in the month of November 2008 against a 

normative coal stock requirement of 22 MT. 

This resulted in increase in number of critical 

and super critical TPSs to 56 & 36 respectively. 

The position started improving from December 

2008 onwards consequent to improvement in 

supply from CIL sources, captive sources and 

also imports by power utilities. The coal stock 

at the end of year 2008-09 improved to 11.7 MT. 

The generation loss of 10.9 BU was reported by 

power utilities during the year due to shortage 

of coal. 

2.14.4 Fuel Infrastructure Committee 

The Fuel Infrastructure Committee was 

constituted by the Prime Minister for coordination 

amongst the Ministry of Railways, Shipping and 

other Ministries dealing with the import of coal 

and matters relating to fuel policy. Chairperson, 

CEA / Adviser (Power), Planning Commission 

are the Conveners of the committee. 

The committee held two meetings i.e. 1 st 

meeting on 7.11.2008 and the 2 nd on 16.02.2009. 

Necessary inputs/ agenda in respect of coal and 

gas were provided by CEA and follow up on 

the decisions taken in the above meetings was 

carried out. 

2.14.5 Coal Availability during 2008-09 

For the coal based generation target of 

510 BUs of the country for the year 2008-09, 

requirement of coal was estimated as 378 Million 

Tonnes (MT), including 12 MT required to bring 

the All India coal stock at power stations from 

11 MT to the normative level and to meet transit 

losses. In the beginning of the year, Ministry of 

Coal/Coal India Limited had given an indication 

that they would make available 293 Million 

Tonnes coal from CIL during the year 2008-09. 

Considering the level of supplies of coal during 

pervious year, 30 MT was expected from SCCL 

and 13 MT from captive mines (Bengal Emta, 

ICML and Panem). Thus, a total of 336 MT coal 

was expected from indigenous sources. To meet 

the estimated requirement of 378 MT of utility 

power stations, an import of 20 MT (equivalent 

to 30 MT gap of indigenous coal) was planned. 

2.14.6 Source-wise Receipt of Coal 

During the year 2008-09, source wise linkage 

and materialization thereof was as given 

below: 



Linkage (MT) Actual Receipt (MT) %Receipt 

CIL 331.566 293.826 88.62 

SCCL 26.830 29.716 110.76 

Captive Mines 15.175 19.079 125.73 

Import 21.330 16.054* 75.26 

Total 394.901 358.675 90.83 

*excludes 1.156 MT in transit at port 

During the year 2008-09, 69% coal was received 

through Indian Railways and 31% through 

their dedicated mode which included coal 

transportation by MGR for pit head thermal 

power stations, own wagons, Ropeway, Road 

etc. A summary of coal received by rail fed 

stations and pit-head Thermal Power Stations is 

given below: 

Mode Linkage Receipt Figures in Million Tonnes 

% Receipt 

Pit-Head 114.111 110.922 97.20 

Rail Fed 280.790 247.753 88.23 

Total 394.901 358.675 90.83 

2.14.7 Overall Coal Supply Position 

Coal supply position for utility thermal power 

stations during the last 3 years and this year, is 

shown as under: 

(Million Tonnes) 

STATUS 

YEAR 

2005-06 2006-07 2007-08 2008-09 

Demand 310.000 332.000 340.000 378.00 

Linkage 308.98 338.553 369.735 394.901 

Receipt (indigenous coal) 282.185 293.637 318.532 342.621 

Receipt (Imported coal) 10.443 9.664 10.153 16.054 

Total Receipt (including Imported Coal) 292.628 303.301 *328.685 *358.675 

Opening Stock (includes Imported coal) 10.499 18.174 14.122 11.037 

Consumption (includes Imported coal) 281.336 302.539 329.632 355.378 

Closing Stock (includes Imported coal) 18.174 14.122 11.037 11.719 

* In terms of equivalent raw coal 

2.14.8 Import of Coal 

During the year 2008-09, against target of 

20.000 Million Tonnes for the year, the power 

utilities in the country imported around 17.210 

Million Tonnes of coal. The utility-wise details 

of annual targets of imported coal, receipts at 

power stations and in transit at ports are given 

below: 


33


Sl. 

No. 

Board/Utility 

Annual Taget of 

Imported Coal 

(MT) 

Receipt at 

Power Stations 

(MT) 

(Figure in Million Tonnes) 

In transit at 

Ports 

(MT) 

Total 

Imported 

(MT) 

(1) (2) (3) (4) (5) (6) = (4+5) 

1. HPGCL 0.500 0.352 0.000 0.352 

2. PSEB 0.500 0.000 0.000 0.000 

3. RRVUNL 0.600 0.402 0.000 0.402 

4. Torrent AEC 0.480 0.545 0.000 0.545 

5. GSECL 1.380 1.026 0.034 1.060 

6. MSPGCL 1.500 1.314 0.000 1.314 

7. Reliance 0.480 0.519 0.039 0.558 

8. APGENCO 0.600 0.706 0.000 0.706 

9. TNEB 1.560 2.295 0.004 2.299 

10. KPCL 0.600 0.604 0.000 0.604 

11. DVC 0.660 0.000 0.000 0.000 

12. CESC 0.490 0.305 0.140 0.445 

13 WBPDCL 0.500 0.318 0.000 0.318 

14. NTPC 8.250 5.502 0.939 6.441 

15. Tata Power Trombay 1.900 2.166 0.000 2.166 

Total 20.000 16.054 1.156 17.210 

National Capital Power Station 4×210 MW (UP) 



2.14.9 Coal Quality Issues 

It was observed that uncrushed/ oversized 

coal was still received by some of the thermal 

power stations in the country causing bottleneck 

in unloading. CEA has been sending statements 

giving details of the complaints about coal quality, 

received from power stations to Ministry of Coal 

and Coal India Ltd. every month. The quality of 

coal has been deteriorating. This has resulted in 

increase in overall Specific Coal Consumption 

of the power stations in the country from 0.731 

kg/ kWh during the year 2007-08 to 0.743 

kg/kWh during the year 2008-09. This resulted 

in increase in the cost of fuel, transportation and 

O&M, as also overloading and breakdown of the 

coal handling plant and equipments and increase 

in unloading time of rail rakes at the power 

stations. 

2.14.10 Monitoring of ash contents in coal 

supplied to MoEF Stations 

As per MoE&F Notification dated 19 th 

September 1997, with effect from 1 st June 2001, 

any thermal power plant located beyond 1000 

Kms from the pit-head and any thermal power 

plant located in urban area or sensitive area 

or critically polluted area, irrespective of their 

distance from pit-head except any pit head power 

plant are required to use coal having annual 

weighted average ash contents of less than 34%. 

There are 36 such identified coal based TPSs in 

the country. The weighted average ash content 

of the coal supplied to these power stations was 

regularly monitored by CEA on quarterly basis. 

These stations were given quarterly linkage of raw 

coal and in some cases washed coal, from various 

sources by the Standing Linkage Committee 

(Short-term) taking into consideration the matrix 

of source of supply which had been prepared to 

ensure an annual weighted average ash content 

of less than 34% ash in the coal used by each 

TPS. As availability of washed/beneficiated coal 

was inadequate to meet the requirement of all 

the 36 TPSs, raw coal of appropriate grade was 

linked for blending. 

CEA impressed on CIL every quarter to 

ensure dispatch of coal from different sources in 

such proportion that the annual weighted average 

ash content of the coal supplied to these TPSs 

would be within the stipulated limit. 

2.14.11 Issues on Fuel Supply Agreement 

(FSA) 

As per New Coal Distribution Policy, power 

utilities were required to sign FSA with the coal 

companies. CIL, on 27 th April 2008, circulated 

a model FSA among the power utilities. The 

last date for signing of FSA is scheduled to be 

31 st March 2009. The model FSA was biased 

in favour of coal companies. There were large 

number of issues which were to be sorted out 

between the coal companies and the power 

utilities. The para-wise detailed comments of 

CEA were forwarded to Ministry of Power. 

Consequent to the intervention of Chairperson, 

CEA major issues relating to Validity of FSA, 

Annual Contracted Quantity (ACQ), Trigger 

Level for Penalty for short delivery/lifting, 

Performance Incentive, etc. were resolved. 

2.14.12 Unloading Constraints 

Pursuant to the decisions taken during 

the meeting taken by Secretary (Power) on 4 th 

June 2008, a committee under the chairmanship 

of Shri V.S. Verma, Member (Planning), CEA 

comprising of representatives from Railways, 

NTPC and CIL was constituted to look into the 

adequacy of unloading infrastructure at thermal 

power stations, wherever high detention time of 

railway rakes was reported and to suggest the 

remedial measures. 


35


The constitution of the Committee is 

as under: 

1. Shri V.S. Verma, Member (Planning), 

CEA- Chairman 

2. Shri Chandan Roy, Director 

(Operations), NTPC- Member 

Shri R.L. Mattoo, Executive Director 

(FM), NTPC- Member 

3. Shri N.C. Jha, Director (Technical), CIL- 

Member 

4. Shri D.P. Pande, Executive Director 

(TTC), Ministry of Railways- Member 

Shri Rinkesh Roy, Director (TT), Ministry 

of Railways 

5. Shri S.H. Khan, Chief Engineeer (OM), 

CEA- Convener 

The report of the committee was submitted 

to Ministry of Power and copies endorsed to 

utilities for taking remedial measures. The same 

was displayed on the CEA website www.cea.nic. 

in also. 

The utilities were requested to take 

immediate steps as per the recommendations 

of the committee to upgrade their unloading 

facilities for reduction of detention time of 

railway rakes. The main recommendations are 

given below: 

1) The thermal power stations where 

Wagon Tipplers are operating without 

Side Arm Charger/Beetle Charger must 

take immediate step to install Side Arm 

Charger/Beetle Charger. 

2) Manual unloading of rakes needs to be 

avoided wherever coal is received through 

BOBR rakes. 

3) Wherever Railways is willing to supply 

BOBR Wagons, arrangements may be 

made for commissioning of Track Hopper 

at the earliest. 

4) All coal companies must install Coal 

Crushers and ensure that only crushed 

coal free from shales/stones is supplied to 

power plants. 

2.14.13 Creation of sub-bands of Usable 

Heat Value (UHV) within existing 

grade of coal and pricing thereof 

For quite some time, Ministry of Coal had 

been suggesting for a changeover from existing 

Ultimate Heat Value (UHV) based pricing to 

Gross Calorific Value (GCV) based pricing of 

coal and to consider possibility of adopting sub 

grading of UHV band as an interim measure to 

incentivise the coal companies to improve coal 

quality. In the present grading based on UHV, 

the band is too large (600-940 K.Cal) to motivate 

the coal companies to attempt improvement in 

quality. Under the aegis of CEA, the CMD’s of 

CIL and NTPC had agreed on 3 rd November 2008 

that each of grades ‘B’ to ‘D’ would have two sub 

grades, ‘E’, ‘F’ & ‘G; would have three sub grades 

and coal with UHV below 1500 kCal/kg would be 

graded as ‘H’. For power sector, coal of grades A 

– F only would be supplied. Coal of grades ‘G’ & 

‘H’ would be reserved for other consumers. The 

bandwidth between the sub grades in the range 

of 270 – 440 kCal/kg was agreed. The guideline 

for working out the prices of the sub grade was 

also agreed. It was also agreed that this system 

would be applied initially for a period of 60 days 

w.e.f 1 st December 2008 at the pit-head stations of 

NTPC having Auto Mechanical Samplers (AMS) 

either at loading end or at the receiving end. 

Based on the outcome, the decision for continuing 

and implementing the system to the other power 

stations where similar facilities were available / 

created would be taken. 

However, the new system is yet to be implemented 

by CIL. 



2.14.14 Gas supply to Gas based Power 

Stations 

Out of total 1,47,965.41 MW installed 

generating capacity in the country as on 31 st 

March 2009, 14,876.61 MW (about 10.05 %) 

was gas/liquid (excluding DG stations)) fuel 

based. CEA monitored the supply of gas to 

power stations of total 13,599.62 MW capacities 

which use gas as the primary fuel. 

2.14.15 Gas Requirement & Supply Position 

The production and supply of gas had not 

been keeping pace with the growing demand of 

gas in the country, including for that of the power 

sector. Supply of gas to gas based power plants 

since 2000-01 has been as under: 

S 

No 

Years 

Capacity at 

the end of 

year (MW) 

Gas 

Requirement* 

(MMSCMD) 

Gas Alloction 

(MMSCMD) 

Average Gas 

Supply $ 

(MMSCMD) 

Shortfall 

(MMSCMD) 

(1) (2) (3) (4) (5) (6) (7)=(4)-(6) 

1 2000-01 9028.70 44.54 36.67 24.40 20.14 

2 2001-02 9432.90 46.31 38.76 24.33 21.98 

3 2002-03 9949.00 48.26 39.47 25.12 23.14 

4 2003-04 10,154.90 49.25 39.47 25.62 23.63 

5 2004-05 10,224.90 49.73 40.95 30.70 19.03 

6 2005-06 10,919.62 53.38 # 35.37 18.01 

7 2006-07 12,444.42 61.18 # 35.10 26.08 

8 2007-08 13,408.92 65.67 # 38.14 27.53 

9 2008-09 13,599.62 66.61 # 37.45@ 29.16 

* Normative gas requirement at 90% PLF taking GCV of gas= 9000 kCal/SCM (except for Ramgarh CCGT for 

which GCV is 4150 k Cal/SCM), station heat rate- 2900kCal/kWh for open cycle and 2000 kCal/kWh for 

combined cycle 

MMSCMD = Million Metric Standard Cubic Metres per Day 

$ Includes R-LNG from 2004-05 onwards 

# Not available 

@ Based on annual fuel supply data furnished by gas based power stations. 

It may be seen from above that the gas supply 

for gas based power stations is inadequate. It 

was enough to operate these stations at about 

52% PLF only during 2006-07 and 2007-08. 

Similarly the average gas supply during 2008-09 

was 37.45 MMSCMD, against the requirement 

of 66.61 MMSCMD (to operate the stations at 

90% PLF), which was sufficient to operate these 

stations at about 50.6% PLF. 

The following gas based power stations (1129 

MW) were stranded due to non-availability 

of gas: 

Sl. 

No. 

Name of Project 

Capacity 

(MW) 

A. Awaiting commissioning due to non-availability of Gas 

Implementation agency/ 

Located in State 

Gas Requirement 

at 90% PLF 

(MMSCMD) 

1 Gautami CCPP 464 Gautami Power Ltd. /AP 2.23 

2 Konaseema CCPP 445 Konaseema EPS / AP 2.14 


37


Sub Total (A) 909 4.37 

B. Commissioned but unable to generate due to shortage of Gas 

1 Jegurupadu CCPP Extn. 220 GVK Industries Ltd./ AP 1.06 

Sub Total (B) 220 1.06 

Total (A+B) 1129 5.43 

2.14.16 Generation loss due to gas 

shortage 

There was a shortage in availability of gas. This 

resulted in loss of generation of power. In case 

of gas based power stations having provision for 

the use of alternate fuels, such as naphtha, HSD, 

generation was augmented by use of such fuels. 

On account of the prevailing high costs of liquid 

fuels resulting in high cost of generation, the 

actual generation using these fuels was, however, 

dependent upon the requirement/acceptance 

by the beneficiaries. Loss of generation due to 

shortage of gas, as reported to CEA and based on 

possible operation of power plants at 90% PLF, 

has been as under: 

S. 

No. 

Year 

Generation Loss during the year in Billion kWh (BUs) 

based on possible operation of gas power plants at 90% PLF 

1 2004-05 23.71 

2 2005-06 23.88 

3 2006-07 26.33 

4 2007-08 31.17 

5 2008-09 33.71 

@ Based on annual fuel supply data furnished by gas based power Station 

2.14.17 Gas Requirement for Gas Based 

Power Projects envisaged during 

11 th Plan. 

Installed generation capacity of gas based 

power stations at the end of 10 th Plan (as on 31 st 

March 2007) was 12444 MW and the estimated 

gas requirement for their operation at 90% PLF 

was 61.18 MMSCMD. The year-wise feasible 

capacity addition programme of gas based power 

plants for the 11 th Plan and estimated additional 

gas requirement for their operation at 90% PLF 

is as given below: 

Year 2007-08 2008-09 2009-10 2010-11 2011-12 Total 

(Actual) (Actual) 

Capacity Addition 

474.7 2522 2590.2 726 7312.9 

(MW) 1000 

Gas Requirement 

(MMSCMD) 

4.41 2.28 12.12 12.25 3.48 34.54 

2.14.18 Monitoring of Captive Coal Mines 

During last few years with growing thermal 

power generation, coal supply is proving to be 

a major cause of concern. With such a massive 

coal based capacity addition planned, there were 

apprehensions that coal companies may not be 

able to cater to the enhanced coal requirement. 

In view of the above facts, it was decided 

to allocate captive mines to the bulk users of 

coal and consequently many power utilities 

have been allocated captive mines. Even though 



Ministry of Coal has specified milestones for 

development of captive coal mines and has been 

monitoring the progress of development by coal 

mines, it was felt that CEA should also monitor 

their progress. 

A monitoring committee consisting of 

officials from CEA and NTPC was formed for 

the above purpose. The monitoring committee 

finalized the list of important milestones to 

be monitored and the captive mine allottees 

were asked to submit the status of their mines 

in the format developed and approved by the 

committee. 

The list of all the Captive Coal Mines allocated to 

Power utilities till date is enclosed at Annexure- 

2C. 

The status of development of mines is 

regularly submitted by the developers and based 

on this a quarterly report on broad status of 

development of captive mines is generated. 

2.14.19 Visits made to various Power 

Stations etc. 

During the year 2008-09, CEA officers 

visited the following thermal power stations in 

connection with issues related to coal supply: 

S. 

No. 

Name of the power 

station/Utility 

Name & Designation of the 

Officers visited 

Date of Visit 

1 Simhadri/NTPC Shri S.H.Khan, CE & 

04.04.2008 

Shri Alok Saxena, Director 

2 Ramagundam/NTPC Shri S.H.Khan, CE & 

07.08.2008 


3 Raichur/KPC Shri S.H.Khan, CE & 

08.08.2008 


4 Bandel/WBPDCL Shri S.H.Khan, CE & 

06.01.2009 


5. Farakka and Kahalgaon/NTPC Shri M.A. Imam, Dy. Director 12.03.2009 

***** 


39


CHAPTER – 3 

POWER SYSTEMS PLANNING AND DEVELOPMENT 

3.1 Transmission Planning 

All issues relating to planning and 

development of Transmission System in the 

country are dealt in the Power System Wing of 

CEA. This includes evolving long-term and shortterm 

transmission plans. The network expansion 

plans are optimized based on network simulation 

studies and techno-economic analysis. This 

also involves formulation of specific schemes, 

evolving a phased implementation plan 

in consultation with the Central and State 

transmission utilities and issues pertaining to 

development of National Power Grid in the 

country and issues relating to trans-country 

power transfer. Transmission planning studies are 

being conducted to identify evacuation system 

from generation projects and to strengthen the 

transmission system in various regions. The 

studies for long-term perspective plans are 

also being carried out on All-India basis for 

establishing inter-regional connectivity aimed 

towards strengthening of the National Grid. The 

National Grid is being evolved to facilitate free 

flow of power across regional boundaries, to 

meet the shortfall of deficit regions from a surplus 

region, for evacuation of power from project(s) 

located in one region to the beneficiaries located 

in other region(s) as well as facilitate trading of 

electricity among buyers and sellers in various 

regions. 

3.2 National Electricity Plan- Transmission 

As per Section 3 of the Electricity 

Act 2003, the CEA has been entrusted with 

the responsibility of preparing the National 

Electricity Plan in accordance with the National 

Electricity Policy and notify such plans once 

in five years. The Act provides that the draft of 

National Electricity Plan should be published 

inviting suggestions and objections from various 

stake holders and the CEA has to obtain approval 

of the Central Government before notifying the 

National Electricity Plan. The following process 

has since been completed: 

1. Central Government has notified the 

National Electricity Policy. 

2. Central Electricity Authority prepared 

a ‘Draft National Electricity Plan – 

Generation’, covering Generation Program 

up to end of 11 th Plan i.e. 2011-12 and 

invited suggestions and objections from 

the stakeholders. 

3. Central Electricity Authority prepared 

a ‘Draft National Electricity Plan – 

Transmission’, covering Transmission 

Program up to end of 11 th plan i.e. 2011- 

12 and invited suggestions and objections 

from the stakeholders. 

4. Comments on the ‘Draft National Electricity 

Plan – Transmission’ were received from 

various utilities and stakeholders. The 

Draft Plan was also discussed in regional 

meetings of all the five Regions. 

5. CEA prepared an updated National 

Electricity Plan consisting of Volume-I 

on ‘Generation’ and Volume-II on 

‘Transmission’. The National Electricity 

Plan as approved by Government of India 

has been notified in August 2007. 

6. Assistance provided to Empowered 

Committee for development of transmission 

system in private sector through target 

based bidding. 



7. Assistance to CERC. 

The National Electricity Plan (the Plan) 

gives details about development of Transmission 

System in the country up to 11 th Plan period. 

Major highlights/status of the Plan are: 

‣ The existing highest level of AC 

transmission in India would be raised from 

400kV to 765kV with construction and 

operation of 765kV transmission system. 

The programme is to have about 5200 

circuit km of 765kV transmission lines 

and 24500 MVA of 765kV transformation 

capacity by 2011-12. The 765 kV level of 

AC transmission in India has already been 

achieved with commissioning of Sipat- 

Seoni 765 kV line. 

‣ A ±800kV Bipole multi terminal HVDC has 

been planned. This would have a capacity 

for 6000 MW of which 3000 MW would 

be utilized for power evacuation from 

Biswanath Chariyali where power from 

Hydro projects in NER would be pooled 

and 3000 MW for power evacuation from 

Alipurdwar in West Bengal or some suitable 

location, where power from Bhutan would 

be pooled. The power evacuated from 

NER/ Sikkim/Bhutan would be brought 

to Agra from where it would be injected 

in NR and WR grids. This would be the 

highest HVDC voltage under commercial 

operation in the world. Total length of 

HVDC Bipoles would be about 11000 km 

by 2011-12. 

‣ The Plan describes Growth Objectives, 

Development Process, Planning Philosophy 

and Criteria for speedy and smooth 

development of transmission system at 

State, Regional and National level with a 

view to optimize energy resources. 

‣ The Plan emphasizes need for a National 

Grid for India and provides detailed 

programme for its development. It is 

planned that, by early of 12 th Plan all the five 

regions in India would by synchronously 

connected. 

3.3 Inter-regional transmission system in 

India – National Power System. 

A national power grid in the country is 

being developed in phased manner. By now, 

all the regional grids have already been interconnected 

and total transmission capacity 

of inter-regional transmission system, as on 

31.03.2009 was 19750 MW. At present, except 

Southern Region, all the other four regions are 

inter-connected in synchronous mode and are 

operating in parallel. 

Initially, a set of inter-regional links 

was developed under the centrally sponsored 

programme for facilitating exchange of 

operational surpluses among the various Regions 

in a limited manner. Because the Regional 

Grids operated independently and had different 

operational frequencies and the power exchanges 

on these inter-regional links took place only in 

radial mode. In 1992, the Eastern Region and 

the North-Eastern Region were connected by 

a 220 kV double circuit transmission line, and 

are operating in synchronism since then. Total 

inter-regional transmission capacity by the end 

of 9 th Plan was 5750 MW. During 10 th Plan i.e. 

2002-07, a total of 8300 MW of inter-regional 

capacities were added. In this effort, major 

achievements were - addition of Talcher-Kolar 

HVDC Bipole, second module of HVDC backto-back 

system between SR and ER at Gazuwaka, 

HVDC back-to-back system between NR and 

ER at Sasaram, synchronous inter-connection 

of NER/ER grid with WR grid by Rourkela- 

Raipur 400kV D/C line, synchronous inter- 


41


connection of NER/ER/WR grid with NR grid 

by Muzaffarpur-Gorakhpur 400kV D/C (quad) 

line and subsequently, one circuit of Patna-Balia 

400kV D/C (quad) line and Agra-Malanpur 

765kV transmission line (operated at 400kV). 

Total inter-regional transmission capacity by the 

end of 10 th Plan was 14050 MW. 

During 11 th Plan i.e. 2007-12, inter-regional 

transmission systems of 24600 MW capacity 

have been planned and it is expected that, by 

end of 11 th Plan, total inter-regional transmission 

capacity of the national power grid would be 

increased to 38650 MW. Out of the programme 

for 11 th Plan, 2400 MW capacity was added 

during 2007-08 and 3300 MW during 2008-09, 

thus a capacity addition of 5700 MW has already 

been added in 11 th Plan up to 31.03.2009. As on 

31.03.2009, the Inter Regional (IR) Transmission 

capacity is 19750 MW. 

Details of existing and planned interregional 

transmission capacity up to end of 11 th 

Plan are shown in Annexure-3A. 

3.4 Development of Transmission System 

for IPPs seeking Long Term Open 

Access (LTOA) 

Prior to 2003 generation was a restricted 

activity requiring approval of the Central/ 

State Govt. With notification of Electricity Act, 

2003 generation has been liberalized and any 

generating company can establish, operate and 

maintain a generating station. The Electricity Act, 

2003 makes it mandatory for the transmission 

licensee to provide non-discriminatory open 

access to its transmission system for use by any 

licensee or generating company for wheeling 

its power on payment of transmission charges. 

The nodal agency designated for providing open 

access in inter-state transmission is the Central 

Transmission Utility, and for intra-state the State 

Transmission Utility. The Generation projects 

proposed by the IPPs would mobilize their own 

capital resources and would supplement the 

planned capacity addition programme. The entry 

of a number of new players in the field of power 

generation could eventually result in competitive 

generation tariffs which is the stated objective 

of the Electricity Act, 2003. Therefore, CEA as 

nodal planning agency is playing a proactive 

role in development of transmission system for 

the IPPs. It is being done in close coordination 

with the CTU, STUs and power utilities. 

Typically, the transmission system associated 

with the generation scheme of an IPP 

comprises: 

• Dedicated transmission lines (DTL) to be 

built by the generator up to the nearest 

pooling point/connection point with the 

grid. 

• Transmission System from CTU grid 

connecting points for onward transmission 

of power. 

• System strengthening of transmission 

system required for absorption of power 

within a region. 

3.4.1 Challenges in planning transmission 

for IPPs 

The IPPs are setting up generating stations 

with the aim of selling power in various segments 

of the electricity market viz. long-term, mediumterm, 

short-term, bilateral or day-ahead power 

exchange. There is no firm knowledge of the 

perspective beneficiaries or delivery point when 

the transmission planning is taken up. At the 

same time, there is a need to create adequate 

transmission in time so that the new generating 

capacity is not bottled up after commissioning. 

Sometimes, the IPPs are eager to finalize 

transmission system because it helps them to 



achieve financial closure. Due to the dynamics 

of the situation explained above, transmission 

system development for the IPPs is turning out 

to be a challenging task. 

3.4.2 Brief details of the evolved integrated 

transmission plan 

A. Integrated transmission system in 

Uttarakhand 

In Uttarakhand, a large number of hydro 

generating projects are proposed in Yamuna, 

Bhagirathi, Alaknanda and Sarda river basins 

during the 11 th and 12 th Plan period. CEA has 

evolved a transmission plan for evacuation of 

power from proposed projects of capacity about 

5000 MW. The evacuation plan consists of 400 

kV pooling stations at Tehri/Koteshwar, Roorkee, 

Kashipur and Pithoragarh where power from 

the proposed hydro projects will be pooled and 

intra-state transmission up to the pooling points 

will be built by Power Transmission Corporation 

of Uttarakhand Ltd. As and when the generators/ 

UPTCL seek long-term open access in interstate 

transmission then inter-state transmission 

requirements would be firmed up. Schematic 

diagram showing the proposed hydro projects in 

various river basins and transmission evacuation 

plan up to the pooling points is at Annexure 3B 

(Exhibit-I). 

B. Integrated transmission system in 

Himachal Pradesh 

In Himachal Pradesh, there are three river 

basins where hydro potential exists. 

Sutluj basin has a capacity of around 7000 

MW. Nathpa Jhakri (1500 MW), Baspa (300 

MW) and Bhawa (120 MW) hydro projects have 

already been developed along with associated 

transmission consisting of 400 kV Triple 

conductors D/C Baspa- Nathpa Jhakri-Nalagarh 

and Nathpa Jhakri-Abdullapur-Bawana. The 

Rampur HEP (432 MW) located downstream 

of Nathpa Jhakri is under construction. For 

evacuation of power from this project, the 

existing Nathpa Jhakri-Nalagarh line would be 

LILO at Rampur. In addition to the above, a 

large number of hydro projects are proposed in 

Satluj basin. An integrated evacuation plan has 

been evolved for projects located in this basin. 

As per the plan, three pooling stations viz 220 

kV pooling station near Chango, 400 kV pooling 

stations at Jhangi and Shelpa Colony ( Karcham 

Wangtoo) have been proposed in addition to the 

existing 400 kV pooling station at Nathpa Jhakri. 

Power from various hydro projects is proposed 

to be pooled at these pooling stations and for 

onward transmission in addition to the existing 

400 kV lines, additional 400 kV D/C Shelpa 

Colony (Karcham Wangtoo) - Abdullapur 

and 400 kV D/C Shelpa Colony(Karcham 

Wangtoo)- Nalagarh-Baghpat are proposed. The 

evacuation plan for generation projects of Sutluj 

basin is at Annexure 3B (Exhibit-II). 

Major existing hydro projects in Ravi basin 

are Chamera-I (540 MW) and Chamera-II (300 

MW). For evacuation of power, 400 kV D/C 

line from Chamera-I to Jullundur and 400 kV 

S/C line from Chamera-I to Kishenpur LILO at 

Chamera-II are existing. In addition to the above, 

a number of hydro projects in Ravi river basin are 

proposed upstream of Chamera. Evacuation plan 

for these projects has been evolved. As per the 

plan, power will first be pooled at 220 kV level 

and then at 400 kV level at Chamera II pooling 

station and for onward transmission a 400 kV 

Chamera-II- Jullundur line is proposed. The 

proposed transmission scheme for the projects is 

indicated at Annexure 3B (Exhibit-III). 

The existing major hydro projects in Beas 

basin are Malana-I (87 MW) and Larji (126 


43


MW). Power from both these projects is being 

evacuated through 132 kV HPSEB system. The 

other major projects proposed in Beas basin are 

Allain Duhangan (192 MW), Malana-II (100 

MW), Koldam (800 MW), Parbati-II (800 MW), 

Parbati-III (501 MW) and Sainj (100 MW). 

Evacuation from Koldam, Parbati II and Parbati 

III HEPs is planned through 400 kV systems. 

The proposed transmission scheme in Beas basin 

is indicated at Annexure 3B (Exhibit-IV). 

C. Transmission System for evacuation 

of power from hydro projects in 

Sikkim. 

In Sikkim, hydro projects of capacity 

of the order of 2362 MW are proposed during 

11 th and early 12 th Plan period. The projects are 

Chujacchen (99MW), Teesta-III (1200 MW), 

Tingting (90 MW), Tashiding (80 MW), Rangit- 

IV (120 MW), Jorethang (96 MW), Rangit-II 

(66 MW), Teesta-VI (500 MW), Rongichu (60 

MW) and Bhasmey (51 MW). 

Transmission System for the hydro projects 

in Sikkim has been planned in a comprehensive 

manner to conserve Right of Way. Two 400 kV 

pooling stations at Mangan in Upper Sikkim and 

New Melli in lower Sikkim are proposed. For 

connectivity to the grid, two 400 kV D/C quad 

lines from Mangan, one via New Melli up to 

a suitable point in Eastern Grid (West Bengal/ 

Bihar) where a 400 kV substation would be 

established are proposed for onward transmission 

of power. The location of the substation would 

be finalized. 

In Teesta-III time frame, one 400 kV quad 

line would be constructed from Teesta-III to a 

suitable point in Eastern Grid (W.Bengal/Bihar). 

When more projects in Sikkim materialize, the 

second 400 kV D/C line could be constructed. 

The transmission plan for IPP projects in 

Sikkim is at Annexure 3B (Exhibit-V). 

D. Transmission System Plan for 

generating projects located in 

Orissa, Jharkhand, Chhattisgarh, 

MP and Maharashtra. 

A large number of IPPs are proposed 

in Orrissa, Jharkhand, Chhattisgarh, MP, 

Maharashtra. The transmission plan for 

evacuation of power from these projects has 

been evolved in a comprehensive manner. 

As per the plan for evacuation of 

power from projects in Orissa, three 765/400 

kV pooling substations are proposed to be 

developed at Angul, Dhenkanal and Jharsuguda 

for pooling of power from different generating 

stations in Orissa. The pooling stations would be 

interconnected in ring form with 765 kV 2xS/C 

lines. High capacity corridors from these pooling 

points for onward transmission of power to NR/ 

WR have been proposed. 

Projects located in Jharkhand viz Essar 

(1800 MW), Electrosteel (1200 MW), Corporate 

(800 MW) would get connected at 400 kV 

to Ranchi 765/400 kV pooling station and 

Adhunik(1000 MW), Dumka (1200 MW) would 

get connected to ER grid at Jamshedpur/Maithon/ 

Gaya. 

For evacuation of power from projects 

in Chhattisgarh and MP, 765/400 kV pooling 

stations at Vindhyachal, Champa, Sipat Raigarh 

and Jabalpur have been proposed. Vindhyachal- 

IV and Rihand-III projects of NTPC would get 

connected to 765/400 kV Vindhyachal pooling 

station. 

IPP projects in MP would get connected to 

Jabalpur pool and Vindhyachal pool depending 

upon their locations. 

Projects proposed in Maharashtra viz JSW 

(1200 MW) and Maharashtra Energy (4000 



MW) would get connected to STU network of 

MAHATRANSCO. 

For utilization and conservation of RoW 

(Right of Way), a 1200 kV evacuation corridor 

has been planned between Raipur-Wardha- 

Aurangabad. This would be initially operated at 

400 kV level and in future would be upgraded 

to 1200 kV level. The transmission towers are 

designed for 1200 kV. 

The main transmission corridors have been 

identified for evacuation of power from Orissa, 

Jharkhand, Chhattisgarh, MP and Maharashtra 

IPPs as well as CPSUs and JVs. The scheme 

is being regularly reviewed depending on the 

finalization of the generation projects. 

The indicative transmission plan is at 

Annexure 3B (Exhibit-VI). 

E. Development Plan for Transmission 

System for the IPPs in 

Southern Region 

A number of Independent Power Producers 

(IPPs) in Southern Region are proposed to come 

up. CEA has evolved a plan for evacuation of 

power from these generation projects within 

Southern Region and also for export of power 

out of Southern Region to Western/Northern / 

Eastern Regions. 

Transmission system for eight (8) 

number of IPP projects with total capacity of 

7680 MW which have made some progress 

in their implementation has been evolved and 

finalized. The evolved transmission system 

inter-alia includes transmission system 

strengthening within Southern Region and 

also strengthening of SR-WR inter-regional 

transmission capacity through Narendra 

(SR) - Kohlapur (WR) HVDC back-to-back 

link and Raichur(SR)-Sholapur(WR) 765kV 

line. The IPP generation projects for which 

transmission systems have been finalized are 

as under: 

Sl. No. Generation Project State Generating Capacity (MW) 

1. Lanco Kondapally AP 375 

2. Gautami AP 1150 

3. Simhapuri AP 540 

4. Meenakshi AP 540 

5. Krishnapatnam (Navyuga) AP 1860 

6. Krishnapatnam APPPDCL AP 1600 

7. Nagarjuna (Lanco) (Mangalore) KAR 1015 

8. Jindal SW TPS KAR 600 

TOTAL 7680 

In addition to above, a number of IPPs 

totaling 24000 MW mainly in coastal areas of 

Andhra Pradesh and Tamil Nadu in Southern 

Region are proposed. Beneficiaries of most 

of these projects are yet to be identified. A 

comprehensive transmission plan identifying 

the transmission corridors for these projects 

has been evolved. These include high capacity 

765kV transmission lines starting from Tamil 

Nadu to Western Region traversing via Andhra 

Pradesh and Karnataka States with intermediate 

sub-stations and associated transmission 

strengthening in Southern Region. The landing 

points in WR, strengthening in WR and system 


45


for onward transmission to Northern Region 

is yet to be identified. A comprehensive 

transmission plan identifying the corridors for 

these projects, their location and capacities are 

depicted in Annexure 3B (Exhibit-VII). 

F. Transmission plan for evacuation of 

power from IPP projects in Arunachal 

Pradesh 

A large hydro potential exists in various 

river basins in Arunachal Pradesh. The two 

hydro projects viz Subansiri Lower and Kameng 

are presently under implementation through 

CPSUs. Evacuation network for absorption of 

power from these projects within NER as well as 

transmission outside NER has been evolved. For 

transmission outside NER ± 800 kV HVDC from 

Biswanath Chareyalli to Agra has been planned 

and presently is in the process of implementation. 

In addition to the above two projects, there are 

large number of hydro projects which have been 

allocated/are in the process of being allocated 

to various IPPs. The various river basins and the 

assessed hydro potential in Arunachal Pradesh is 

as under: 

• Lohit Basin (5700 MW), 

• Dibang Valley (10410 MW), 

• Siang Basin (15881 MW), 

• Tawang Basin (1665 MW), 

• Subansiri Basin (14612 MW), 

• Kameng Valley (4705 MW) 

For evacuation and transmission of power 

from various hydro projects, an evacuation 

plan has been evolved. The plan consists of 

pooling of power from various hydro stations 

at various pooling points in Arunachal/NER. 

For transmission of power beyond the pooling 

points within NER and also for transmission 

outside NER, the transmission network would 

be evolved when the status and progress of 

various IPPs is known. The transmission plan 

would also need to be periodically reviewed 

and implemented in phases depending upon the 

progress of implementation of hydro projects. 

An exhibit showing the basin wise 

proposed evacuation paths/routes & various 

pooling points is as per Annexure 3B 

(Exhibit-VIII). 

3.5 Transmission System Planning 

Studies carried out during 2008-09 

Transmission system planning studies 

were carried out to evolve a composite system 

for evacuation of power from generation projects 

envisaged beyond 11 th Plan. Studies were carried 

out to identify long-term system strengthening 

requirements in various regions/states. A list of 

studies carried out to evolve long term perspective 

plan is shown below: 

A. Southern Region and All-India 

‣ Transmission System studies for evacuation 

of power from Vallur TPS(3x500MW) and 

North Chennai TPS St-II (2x600MW) 


of power from Kothagudam TPS Stage 

–VI (1x500 MW). 

‣ System studies for strengthening of 400kV 

ring around Bangalore area. 

‣ Transmission system for evacuation of 

power from Yeramaras (2x800MW) and 

Edlapur (1x800 MW). 

‣ Transmission System studies for 

evacuation of power from Bhoopalapally 

St-1 (500MW) and St-II (600MW) in 

Andhra Pradesh. 




of power from Tilaiya UMPP (4000MW) 

in Jharkhand. 

‣ System Strengthening with 400kV S/S at 

Chulliar in Kerala. 

‣ System Studies for 400/220kV transformer 

at Berhampur 400kV Sw.Stn. in Orrisa. 

‣ System studies for establishment of 

connectivity to Yelahanka 2x500 MVA, 

400/220kV S/S in Karnataka. 

‣ System studies to mitigate overloading 

of 400/220kV transformers in Hyderabad 

area. 

B. Northern Region 

‣ Revised system studies for power 

evacuation from Nimo Bazgo at 66 kV and 

power transmission to Leh and Kargil area 

of Ladakh. 

‣ Studies for evacuation of power from the 

following thermal power projects in U.P. 

were carried out. 

a. Anpara 'C' - 1000 MW 

b. Anpara 'D' - 1000 MW 

c. Bara HEP - 1980 MW 

d. Mejia - 1980 MW 

e. Karchana HEP - 1320 MW 

f. Parichha Extn - 500 MW 

g. Tanda Extn - 1000 MW 

h. Roza TPS - 1000 MW 

i. Hardwaganj - 500 MW 

‣ Studies were carried out for evolving 

the power evacuation arrangement from 

various thermal projects in Rajasthan. 

‣ Studies for evacuation of power from 

the following thermal power projects in 

Haryana were carried out : 

a) Hissar - 1200 MW 

b) Jhajhar-I – 1500 MW(Haryana 750 

MW-50%) 

c) Jhajhar –II – 1320 MW 

d) Adani Power injected at Mohindergarh 

- 1424 MW 

‣ Transmission System associated with 

generating projects like Talbandi Sabo 

(2000 MW), and Rajpura(1320 MW). 

‣ Transmission planning studies of 765 kV 

System for Central part of Northern Grid. 

‣ Transmission system associated with 

Dadri-II TPS (2x490 MW) 


Tilaiya UMPP (4000 MW)-NR portion. 

‣ Preparation of reports relating to the power 

evacuation arrangement from Rabi, Beas, 

Sutluj, Chandrabhaga basin in Himachal 

Pradesh. 

‣ Load flow studies carried out to study the 

revised project report for infrastructural 

development at 220 kV & 132 kV 

transmission level under Prime Minister’s 

Reconstruction Plan for J&K. 

‣ Transmission planning studies for 

strengthening of 400 kV and 220 

kV network in and around Delhi for 

Commonwealth Games 2010. 


47


‣ Requirement of shifting of Sasaram HVDC 

Module. 

C. Eastern Region 

‣ Transmission planning studies for 

strengthening of 400 kV and 220 

kV network in Orissa for testing and 

finalization proposals on the basis of the 

study report submitted by OPTCL. 


Tilaiya UMPP (4000 MW). 

‣ Load flow study of DVC with various 

alternative and contingency to identify 

suitable transmission system requirements 

to evacuate power from 710 MW Mejia 

Ext. TPS (unit 4, 5 & 6) and Chandrapura 

Ext. TPS (2x250 MW). 

D. Western Region 

‣ Transmission system associated with the 

Tilaiya Ultra Mega Power Project (4000 

MW) in Jharkhand, Nabinagar (1000MW) 

of Railways and NTPC, Barh-II (1320 

MW), Rihand-IV (1000MW), Vindhyachal- 

IV (1000MW) and Mauda (1000MW) of 

NTPC, and IPPs in Jharkhand, Orissa, MP, 

Chattisgarh and Maharashtra. 

‣ Transmission System at 400kV and 765kV 

in Maharashtra-Proposal for Intra-state 

transmission system of STU, Evacuation 

system from generating stations (MSPGCL, 

MAHADISCOM and IPPs). 

3.6 Examination and appraisal of 

Transmission Schemes for approval 

under Section 68 of Electricity Act 2003 

A list of transmission proposals examined for 

approval under Section 68 of Electricity Act, 

2003 is given below: 

A. Northern Region 


Kotlibhel HEP 

‣ Northern Region System Strengthening 

Scheme - XIII 


Scheme – XIV 


Scheme – XV 


Scheme – XVI 


Scheme – XVII 


Scheme – XVIII 


Scheme – XIX 


Scheme – XX 

‣ Northern Regional System Strengthening 

Scheme – XXI 

‣ Transmission system of Northern Region 

for Sasan and Mundra UMPP 

‣ Laying of dedicated 2500MW (± 500 

MW) HVDC Mundra –Mohindergarh 

transmission line. 

‣ Revised proposal for construction of 

132 kV line for evacuation of power of 

Malana- II HEP. 


Parbat-II and Koldam HEP 




Karcham Wangtoo HEP. 


Allain Dungan HEP. 

‣ 765 kV system for central part of the 

Northern grid 


Rampur HEP. 

‣ System strengthening in Northern Regional 

Grid for Karcham Wangtoo HEP 

‣ Northern Regional Transmission 

Strengthening Scheme (NRTSS) 

B. Eastern Region 

‣ Transmission system for export of power 

from different generation projects in 

Sikkim to NR/WR 

‣ “PGCIL scope of works associated with 

transmission schemes being developed 

by Independent Transmission Provider 

(ITPs)”. 

‣ “Transmission System for development of 

pooling station in Sikkim and transfer of 

power to a new pooling station in Northern 

part of West Bengal/Bihar”- under Section 

68 of the Electricity Act, 2003. 

‣ 400kV D/C Teesta-Kishengang pooling 

station line via Magan pooling station by 

JV company of PGCIL and M/s Teesta 

Urja Ltd. 

C. Western Region 

‣ Transmission system for South West 

Interconnection 


Korba –III generation project 


Western Region System Strengthening 

Scheme-XI (WRSS –XI) 

D. Southern Region 


Simhadri-II Generation Project of NTPC 

– Line connecting the Generation to the 

Grid 


Krishnapatnam UMPP 

‣ Transmission system for South-West 

Interconnection 

‣ System Strengthening Scheme in Southern 

Region – X. 


Region – XI 


Region – XII. 

‣ 400 kV dedicated transmission line from 

366 MW expansion project to 400 kV 

Vijayawada Switchyard of PGCIL. 

E. North-Eastern Region 


Pallatana GBPP (740 MW) and Bongaigaon 

TPS (750 MW) 

‣ North East-Northern/Western Region 

Interconnector-I (Revised scope) 

3.7 Standing Committee Meetings 

Standing Committees on transmission 

planning for resolving issues related to 

transmission system planning have been 

constituted in 1980s and during April 2008 to 

March 2009 - Two no. for Northern Region, 


49


One no for Eastern Region, One no. for Western 

Region, Two no. for Southern region and one 

no. in North East Region have been convened. 

Apart from this several meetings were held 

with constituents of WR and NR for arriving at 

consensus on the issue of sharing of transmission 

charges of Sasan and Mundra UMPP and WR- 

SR Inter Regional link. 

The issues pertaining to transmission 

system planning which were taken up during 

these meetings are given in Annexure – 3C. 

3.8 Additional Works 

• Assistance provided to Empowered 

Committee for development of transmission 

system in private sector through tariff 

based bidding. 

• Assistance to CERC. 

3.9 Consultancy services and assistance 

to various utilities 

(i) 

(ii) 

Power Development Department, Govt 

of J&K: 220kV and 132kV Transmission 

Projects under Prime Minister’s 

Reconstruction Program. 

Bhutan Power Corporation, Govt. of 

Bhutan: 132kV and 66kV Transmission 

and substation works. 

(iii) WAPCOS: Transmission and Substation 

work relating to Salma Hydro Project, 

Afganishtan. 

(iv) Damodar Valley Corporation: Design 

of 220kV Multicircuit,132kV and 33kV 

Transmission Line Towers. 

(v) 

Assistance to Delhi Transco. Ltd and 

APTRANSCO in preparation of technical 

specification and evaluation of tenders for 

220 kV & 132 kV XLPE Cables and GIS 

Substation. 

3.9.1 Representation/Nomination in 

the Committees 

Standing Committee under the 

Chairmanship of Chief Engineer (SETD), CEA 

has been constituted to investigate causes of 

failure and to suggest remedial measures to 

avert/minimize the failure for following: 

a) Transmission line towers of 220kV & 

above Voltage Class. 

b) Various substation equipment of 220 kV 

and above Voltage Class. 

3.10 Analysis of causes of failure of 

transmission line tower and substation 

equipment 

3.10.1 Transmission Line towers 

As a part of activity of Standing Committee 

to assess the cause of failure of transmission 

line towers of 220 kV & above voltage class, 

failures of 400 kV & 220 kV Transmission line 

towers of PGCIL, MPPTCL were investigated 

and remedial measures suggested. Standing 

Committee of Experts submitted report in respect 

of the following lines: 

• 400 kV S/C Farraka-Durgapur Transmission 

Line ( PGCIL) 

• 400 kV D/C Vindyachal-Jabalpur(ckt 3&4) 

Transmission Line (PGCIL) 

• 400 kV S/C Kishanpur-Wagoora 

Transmission Line(PGCIL) 

• 220 kV D/C Hissar (PGCIL) S/S-Hissar 

Transmission Line 



3.10.2 Substation Equipment 

As a part of activity of Standing Committee 

to assess the cause of failure of various S/S 

equipment of 220 kV and above voltage class, 

investigation in respect of the following utility 

was carried out and recommendation sent to 

concerned utility. Report is also available in 

CEA website. 

a) Delhi Transco. Ltd.: 

Failure of 400/220/33 kV, 315 MVA 

transformer at Baranauli on 11.02.2008. 

3.11 Residual Life Assessment (RLA) of 

Substation Equipment 

Under Pilot Project for RLA, following 

diagnostic tools were procured and deployed at 

220/33 kV Mudsighi- 400/220kV Kolhapur-II 

Substation of MSETCL at Kolhapur. 

i) Digital Earth Tester 

ii) 

iii) 

Transformer Winding Resistance Meter 

Contact Resistance Meter 

iv) Automatic relay test kit (3 phase) 

v) Circuit Breaker Operation Analyzer 

vi) 

Leakage current monitor for lightning 

arrester 

vii) Automatic Capacitance & Tan Delta 

Measuring Equipment. 

Using above diagnostic tools, MSETCL 

could save premature failure of number 

of substation equipment. These diagnostic 

equipments were deployed between 2003-2005 

and are in continuous use since then. Based on 

the experience and benefits, MSETCL have 

procured number of similar diagnostic tools and 

have deployed in their substations. 

The following diagnostic tools which were 

earlier used in MSETCL are at present being 

utilized by GETCO, Ahmedabad: 

1. On line Dissolved gas Analyzer for 

Transformer 

2. Partial Discharge Measuring Equipment 

for Transformer 

Frequency Response Analyzer which is 

presently available with CEA can be utilised by 

any for power utilities in the country. 

The basic purpose of deployment of these 

diagnostic tools with MSETCL and GETCO was 

to create awareness among the power utilities in 

State Sector regarding use and benefits of various 

modern diagnostic tools. Engineers of CEA visited 

the sites of MSETCL and GETCO regularly 

for interaction and discussion various issues 

relating to use of diagnostic tools and creation 

of data base of various maintenance activities 

which would provide valuable information to 

O&M staff for taking early action to avoid any 

major failure. 

3.12 Regulations & Committee Reports 

(i) 

(ii) 

Regulations on construction of Electrical 

Plants and Electric Lines prepared under 

Chairmanship of Member(PS), CEA 

submitted to MoP. 

Committee constituted by CEA to review 

the insulation requirement of EHV 

transmission lines of various voltages, 

submitted the report to MoP. 

(iii) Committee constituted under the 

Chairmanship of Member(PS), CEA 

to consider various issues regarding 

indigenous production of CRGO material, 

submitted recommendations to MoP to 


51


have inter-action with Ministry of Steel 

for establishment of new facility for 

indigenous production of CRGO through 

participation of private companies like 

Jindal Steel, Tata Steel etc. 

3.13 Construction Monitoring of 

Transmission Projects 

The monitoring of construction of 

transmission lines and sub-stations at voltage 

levels of 220 kV and above is being carried out 

with a view to achieve completion of transmission 

system to ensure evacuation of power from new 

generating power stations as well as to strengthen 

the power system network in the country. For the 

year 2008-09, programme for stringing of 653 

ckm of 765 kV,1250 ckm of ± 500 kV HVDC, 

8025 ckm of 400 kV and 6493 ckm of 220 kV 

transmission lines was envisaged. Against this 

programme, the stringing of transmission lines 

actually achieved during the year 2008-09 

was 564 ckm of 765 kV,1180 ckm of ± 500kV 

HVDC,6827 ckm of 400 kV and 4171 ckm of 

220 kV lines. Details of the transmission lines 

completed during the year 2008-09 are given in 

Annexure– 3D. 

Voltage wise/sector wise actual 

achievement vis-à-vis programme for the 

year 2008-09 in respect of lines are given in 

Charts I to IV. 

Chart-I 

Achievement of 765 kV transmission lines during the year 2008-09 



Chart-II 

Achievement of ± 500kV HVDC transmission lines during the year 2008-09 

Chart-III 



53


Chart-IV 


In respect of transformation capacity, a 

programme of addition of 9885 MVA at 400 kV and 

14943 MVA at 220 kV was envisaged for the year 

2008-09. Against this programme, the achievement 

during 2008-09 was 7995 MVA at 400 kV and 11234 

MVA at 220 kV respectively as shown in the Charts V 

and VI. Details of the sub-stations completed during 

2008-09 are given in Annexure–3E. 

Chart-V 

Achievement of 400 kV substations during the year 2008-09 



Chart-VI 

Achievement of 220 kV substation during the year 2008-09 

3.14 Inspection of Electrical Installations 

The Indian Electricity Act, 2003 stipulates 

statutory inspection of electrical installations 

by Central and State Inspectors in respect of 

installations within their respective jurisdictions. 

The Electrical Inspectorate at the Central and 

State levels are assisted by designated Electrical 

Engineers to discharge these functions. The 

Chief Engineer (Electrical Inspectorate) has 

been appointed as Chief Electrical Inspector for 

the Central Government installations all over 

India and those within Union Territories.The 

Chief Electrical Inspector is assisted by five 

Regional Inspectorial Organizations (RIO’s) with 

Headquarters at New Delhi, Chennai, Shillong, 

Mumbai & Kolkata in discharging the various 

responsibilities, briefly described as under : 

(a) 

Statutory periodic inspection of electrical 

installations and issue of notices to the 


(b) 

(c) 

(d) 

owners of installations for compliance 

under Rule 46 of the Indian Electricity 

Rules, 1956. 

Scrutiny of references received under Rule 

63/47A of I.E.Rules, 1956 for inspection 

and granting approval for energisation 

of High/Extra high voltage installations/ 

generating units. 

Inspection of Electrical installations in 

Cinema house and issue of no objection 

certificates for grant of annual license to 

the cinema house under the respective 

Cinematography Act in force in the Union 

Territories. 

Issue of Cinema operator’s certificate 

under Cinematography Act in force in the 

Union Territories and State of Goa. 

(e) Investigation of fatal and non-fatal 

electrical accidents and remedial measures 

55


(f) 

(g) 

to be taken to avoid recurrence of such 

accidents in future. 

Scrutiny of cases regarding unauthorized 

construction under overhead lines 

involving infringement of Rules 79, 80 & 

82 of I.E.Rules, 1956. 

Issue of Electrical Contractor licenses and 

competency certificates to Supervisors and 

wireman through the Licensing Board in 

respect of Union Territory of Puducherry. 

(h) 

Scrutiny of applications for relaxation of 

I.E.Rules and granting of such relaxation, 

if necessary. 

3.15 Resume of Inspection Work Done 

The Electrical Inspectorate and its five 

Regional Inspectorial Organisations inspected 

a total number of 181726 equivalent Medium 

Voltage installations and collected a revenue of 

Rs. 342.83 lakhs during the year, the region-wise 

break-up of which is given below: 

RIO 

Eq. MV installations (Nos.) Fee Collected (Rupees in Lakhs) 

2007-08 2008-09 2007-08 2008-09 

N Delhi 33,433 58572 45.88 102.00 

Chennai 56,765 27195 100.06 81.29 

Mumbai 57,320 34643 107.03 59.41 

Shillong 18,475 16605 40.14 26.59 

Kolkata 40,000 44711 105.49 73.54 

Total 205,993 181726 398.6 342.83 

3.15.1 Major Achievement in Term of 

Inspection during the Year 2008-09 

(Important Installations Inspected) 

A) New Inspection Cases (Rule 63/47A) 

a) 765kV Bays at Seoni, 400/220 kV S/S 

at Roorkee, Baripada, Gwalior, Wardha, 

Rajgarh, Misa, Damoh, Kadappa, 

Tirunalveli, Warangal, Karur, Udumalpet, 

Kudankulam (along with 220 kV GIS). 

220/132kV S/S at Sitarganj, Dahej, 220/6.6 

kV S/S of DVC at MTPS, 220kV/33 kV S/S 

at Barjora, 220 kV S/S at Kalyaneswari, 

132 kV S/S at patratu, SAIL at BSP and 

Rangia S/S. 

b) Transmission lines : 765kV Sipat-Seoni 

S/C, Seoni – Wardha S/C and Agra- 

Gwalior 2nd Ckt, 400 kV Kota-Merta 

D/C, Zarda – Kankroli D/C, LILO of 

Jaipur – Hisar at Bhiwadi, LILO of 

Rishikesh – Muzaffarnagar at Roorkee, 

Ranchi – Sipat D/C, Wardha – Akola D/C, 

Akola- Aurangabad D/C, BSP – NTPC 

(JV) D/C, LILO of Kolar- Sriperumbudur 

D/C, LILO of Ramagundam-Khamman, 

Madurai – Pugalur. 220 kV LILO of 

Bareilly - Tanakpur at Sitarganj, 132 kV, 

Deothang - Rangia S/C. 

c) Generating Units; RAPP (Unit-5&6) of 

NPCL, and 500 MW, NTPC Sipat. 

B) Periodical Inspections (under Rule 

46 of I.E. Rules 1956) 

Extra emphasis was laid on Periodical 

inspection of large plants in Power and 

Petrochemical Sector under Rule 46 of I.E. 

Rules, 1956. Important projects covered 

are : 



a) Generating plants: Dhauliganga HEP, 

Narora Atomic Power Plant, Dadri Gas 

Power Station, Dadri Thermal Power 

Station, Badarpur Thermal Power Station, 

Bairasiul Hydro Power Station, Anta Gas 

Power Station, Auraiya Gas Power Station, 

Talcher Super Thermal Power Station, 

Doyang HEP, Khandong HEP, Ranganadi 

HEP, Tarapur Generating Station and 

Kayamkulam (RGCCPP). 

b) HVDC terminal at Dadri, 400/220 kV 

S/S at Moga Gorakhpur, Bhiwadi, Agra, 

Ludhiana, Kanpur, Hisar, Kota, Malerkotla, 

Patiala, Balipara, Ranganadi, Jabalpur, 

Talapalli Narendra, Vijaywada. 220 kV 

S/S at Faridabad, 132 kV Substations at 

Haflong, Badarpur, Kumarghat, Khliehriat, 

Zero, Khupi, GAIL at Vijaypur and 

National Ferilizer Ltd. at Vijaypur. 66 kV 

S/S of GAIL at Samaghikli, Vagodia and 

Kandla Port Trust. 

100 MVA, 220/132 Kv Transformer at Achalia Sub-Station, GETCO 

***** 


57


CHAPTER – 4 

GRID MANAGEMENT 

4.1 Organizational Structure in Grid 

Operation and Management 

All decisions with respect to grid operation 

in the Region are taken by the Regional Power 

Committee (RPC). The Regional Power 

Committee in each Region has been established 

by the Central Government under the provisions 

of sub-section (55) of section 2 of the Electricity 

Act, 2003. The RPC is a conglomerate of all the 

States and the Union Territories of the Region 

and other players partaking in grid operation, 

i.e. generating companies, transmission utilities, 

distribution utilities, power traders, etc. Its 

Secretariat is manned by the Central Electricity 

Authority (CEA). Regional Power Committee 

operates through a number of Sub-Committees, 

viz. Technical Coordination Sub Committee, 

Operation Sub Committee, Commercial Sub 

Committee, Protection Sub Committee and 

System Studies Sub Committee. The Operation 

Sub Committee, meet every month to review the 

grid operation in the previous month and plan grid 

operation for the next month. The Commercial 

Sub Committee carry out the energy accounting 

in the Region on a monthly basis and also the 

weekly billing for Unscheduled Interchanges 

and Reactive Energy. The Protection Sub 

Committee discuss and finalise protection 

schemes including protection coordination. 

The System Studies Sub Committee meet 

periodically for the purpose of System Studies. 

The Technical Coordination Sub Committee 

meet before the Regional Power Committee for 

putting up matters for decision in the Regional 

Power Committee. The RPCs play an important 

role in planning grid operation, since they are 

responsible for protection coordination, outage 

planning of generating units and transmission 

system, planning reactive compensation etc. 

Member (Grid Operation), CEA is a Member 

of the Regional Power Committee and helps in 

arriving at amicable solutions in case of disputes 

between conflicting interests of the Members of 

the Committees through unbiased decisions. 

CEA analyses the power supply position 

in the country, prepares the “All-India monthly 

power supply position”, coordinates all matters 

of grid operation and management between 

the five Regions, coordinates enquiry of grid 

disturbances, recommends to the Ministry 

of Power the quantum of allocation from the 

unallocated quota of Central Generating Stations 

(CGSs) and also coordinates the implementation 

of the allocation through the Regional Power 

Committees. CEA forecasts anticipated power 

supply position on monthly basis for all the 

States and Union Territories for the next financial 

year, brings out Load Generation Balance Report 

(LGBR) and is also responsible for Regulations 

on matters pertaining to grid operation. The real 

time operation of the power system is looked 

after by the Regional Load Despatch Centres 

(RLDCs) set up in the five Regions and on the 

national level by National Load Despatch Centre 

(NLDC). Regulations for inter-State transmission 

of electricity are made by the Central Electricity 

Regulatory Commission and coordinated by 

NLDC and RLDCs. 

4.2 Power Supply Position 

The Central Electricity Authority takes 

out the All India Power Supply Position on a 

monthly basis, both in terms of energy and peak 

demand giving the energy requirement, energy 



availability and energy shortage in Million Unit 

(MU) as well as in percentage and the peak 

demand, peak met and peak shortage both in 

terms of Mega Watt (MW) and percentage. The 

total energy requirement in the country during 

2008-09 was 777,039 MU as against 739,343 

MU during the previous year, registering an 

increase of 5.1%. The total energy availability 

in the country during 2008-09 was 691,038 MU 

as against 666,007 MU during the previous year, 

registering an increase of 3.76%. The energy 

shortage during the year 2008-09 therefore 

increased from 73,336 MU (9.9%) to 86,001 

MUs (11.1%). The peak demand during the year 

2008-09 was 109,809 MW as against 108,866 

MW during the previous year, registering an 

increase of 0.87%. The peak demand met during 

the year 2008-09 was 96,785 MW as against 

90,793 MW during the previous year, registering 

an increase of 6.6%. The peak shortage therefore 

decreased from 18,073 MW (16.6%) to 13,024 

MW (11.86%). An overview of Region-wise 

power supply position in terms of energy and 

peak demand for the year 2008-09 is presented in 

Exhibit-I and Exhibit-II respectively. The State / 

Region-wise power supply position during the 

year 2008-09 is enclosed at Annexure-4A. The 

shortages increased in all Regions except the 

Northern Region, which got the benefit of thermal 

power from Central Stations of Eastern Region 

in lieu of allocation of power from the 1,020 MW 

Tala Hydro-electric Power Station in Bhutan to 

the Eastern Region, as per previous agreement. 

Energy requirement and Peak Demand grew at 

the fastest rate in Southern and Eastern Regions, 

their Energy Requirements growing 8.7% and 

8.2% and Peak Demand growing 8.1% and 7.2% 

respectively in 2008-09 vis-à-vis 2007-08. 

Exhibit-I 

Region Wise Power Supply Position (Energy) 


254475 

Energy (in Mu) 

250,000 

200,000 

150,000 

100,000 

227104 

201951 

213715 

204012 

188794 

82041 78444 

9407 8134 

50,000 

0 

NR WR SR ER NER 

Requirment 

Availability 


59


Exhibit-II 

Region Wise Power Supply Position (Demand) 


Demand ( in MW ) 

40,000 

30,000 

20,000 

10,000 

37034 

29504 

37240 

30153 28958 

26245 

12901 11789 

1820 1358 

0 

NR WR SR ER NER 

Peak Demand 

Peak Met 

4.3 Optimum Utilization of available 

Generating Capacity - Inter Regional 

Exchanges of Power 

Northern, Western, Eastern and North- 

Eastern Grid with an installed generating 

capacity of 107,759 MW as on 31/03/2009 and 

peak load of 80,851 MW for the year 2008-09 

were connected through synchronous links. 

Southern Region, with an installed generating 

capacity of 40,130 MW as on 31/03/2009 and 

peak load of 28,958 MW for the year 2008-09, 

was connected with Eastern Region and Western 

Region through asynchronous HVDC links. The 

total inter-regional transmission capacity as on 

31.3.2009 is 19,750 MW. The power transfer 

capacity as on 31 st March 2009 was 6,330 MW 

between Eastern Region and Northern Region, 

2,990 MW between Eastern Region and Western 

Region, 3,630 MW between Eastern Region and 

Southern Region, 1,260 MW between Eastern 

Region and North Eastern Region, 3,220 MW 

between Western Region and Northern Region 

and 1,720 MW between Western Region and 

Southern Region. Synchronous operation of the 

Northern, Western, Eastern and North-Eastern 

Regional Grids and asynchronous operation 

of the Combined Grid with the Southern Grids 

helped in export of surplus/ unutilised power 

across various Regions. 

All Regional grids experienced shortages 

of varying degrees as well as certain seasonal/ 

off-peak surpluses. These surpluses were 

exported by surplus States of all the Regions. 

Eastern Region was the net exporter, whereas 

Northern, Western, Southern and North-Eastern 

Regions were net importers of power during the 

year. 

Govt. of India has set up Central 

Generating Stations through Undertakings, viz. 

National Thermal Power Corporation (NTPC), 

National Hydro Power Corporation (NHPC), 

Nuclear Power Corporation (NPC) etc. in which 

the States have various shares. About 85% 

of the installed capacity is distributed as firm 

shares, whereas about 15% is the unallocated 

quota, which is allocated by Govt. of India to 

the States depending upon relative shortages and 

contingent conditions. CEA keeps a close watch 

on the power supply position and recommends to 

the Ministry of Power the quantum of allocation 

from the unallocated quota. CEA also coordinates 

the implementation of the allocation through the 

Regional Power Committees. 



Open Access is a key provision in the 

Electricity Act, 2003 for utilisation of power in 

surplus areas by needy states/utilities in deficit 

areas, besides bringing about competition and 

hence efficiency. All the above transactions took 

place through the provision of short-term open 

access. The growth of inter-state short-term 

Open Access transactions for the last four years, 

in terms of number of transactions and volume 

of transactions, is shown in Exhibit- III. 

The inter-regional energy exchanges, which 

included the long-term and short-term open 

access transactions, was 23,405 MU during the 

year 2008-09, as compared to 20,061 MU during 

the previous year, showing a growth of 16.7%. 

An over view of inter-regional energy exchange 

during 2008-09 is presented in Exhibit – IV. 

Details of Inter-regional exchanges of energy 

among the Regions during 2008-09 and 2007- 

08 are given in Table – I. The inter-regional 

exchanges helped a number of States / utilities 

in all the Regions to bridge the gap between 

demand and supply of power. 

Exhibit-III 

Inter-State Open Access Transactions 


61


Exhibit-IV 

Inter-Regional Exchanges for the year 2008-2009 

Table-1 

Inter-Regional Exchanges for the year 2007-2008 & 2008-2009 

(in MU) 

Region 

From 

To 

2007-2008 2008-2009 

i) Northern Western 900.6 1,337.4 

Southern 427.7 798.9 

Eastern 0.2 21.9 

North-Eastern 0.0 157.5 

Sub Total 1,328.5 2,315.7 

ii) Western Northern 1,106.3 1,784.8 

Southern 110.1 1,909.4 

Eastern 29.9 36.1 

Sub Total 1,246.3 3,730.3 

iii) Southern Northern 2,175.0 1,413.4 

Western 2,145.4 1,488.1 

Eastern 127.0 12.4 


Sub Total 4601.6 2,913.9 

iv) Eastern Northern 7,370.2 8,161.0 

Western 2,940.1 3,236.6 



Southern 1,514.4 1,417.5 


Sub Total 12,268.5 13,570.7 

v) N-Eastern Northern 393.9 383.0 

Western 129.3 412.5 

Southern 60.8 53.9 

Eastern 31.7 24.8 

Sub Total 615.7 874.2 

Total 20,060.6 23,404.8 

4.4 Operation of Regional Grids 

4.4.1 Northern Regional Grid 

The Northern Grid has an installed capacity 

of 38,723 MW as on 31-3-2009 consisting of 

22,352 MW thermal, 13,425 MW hydro, 1,180 

MW nuclear and 1,766 MW renewable energy 

sources. It had a peak load of 33,034 MW (exbus) 

during the year. The Northern Grid faced an 

energy shortage of 11.1% and a peaking shortage 

of 10.7% during the current year as compared to 

energy and peak shortages of 10.8% and 9.1% 

respectively during previous year. Northern 

Region was the biggest importer of power 

importing 8161.0 MUs from Eastern Region, 

1,413.4 MU from Southern Region, 1,784.8 MU 

from Western Region and 383 MU from North 

Eastern Region. Power was transferred from 

Eastern Region to Northern Region over 500 MW 

HVDC back-to-back station at Sasaram, 2,000 

MW Muzaffarpur-Gorakhpur 400 kV D/C line, 

1,600 MW Patna – Balia 400 kV D/C line and 

1,600 MW Biharshariff – Balia 400 kV D/C line. 

Northern Region is also connected to Western 

Region through Agra – Gwalior 765 kV line 1&2 

(presently being operated at 400 kV) and 500 

MW HVDC back to back link at Vindhyachal. 

With the coming up of Agra – Gwalior, Patna – 

Balia and Biharshariff – Balia lines, the stability 

of the combined grid has improved and also 

this has facilitated free flow of power from the 

surplus areas to deficit areas. 

4.4.2 Western Regional Grid 

The Western Grid has an installed capacity 


32,653 MW thermal, 7,448 MW hydro, 1,840 

MW nuclear and 4,024 MW renewable energy 

sources. It had a peak load of 37,240 MW (exbus) 

during the year. The Western Grid faced an 

energy shortage of 16% and a peaking shortage 

of 19% during the current year as compared to 


respectively during the previous year (2007-08). 

Power transfer from ER to WR is taking place 

over 220 kV triple circuit Korba – Budhipadar 

AC lines and 400 kV Raipur- Rourkela double 

circuit AC link (with series compensation) 

and with Southern Region through 1,000 MW 

HVDC back to back link at Chandrapur. Besides, 

there is a 500MW HVDC back to back link at 

Vindhyachal for power transfer with NR. 

4.4.3 Southern Regional Grid 

The Southern Grid has an installed 

capacity of 40,130 MW as on 31-3-2009 

consisting of 21,028 MW thermal, 10,954 

MW hydro, 1,100 MW nuclear and 7,048 MW 

renewable energy sources. It had a peak load 

of 28,958 MW (ex-bus) during the year. The 

Southern Grid faced an energy shortage of 

7.5% and a peaking shortage of 9.4% during 

the current year as compared to energy and 

peak shortages of 3.2% and 9.0% respectively 


63


during previous year. The Southern Region 

has been both importing and exporting power 

from/ to other Regions during the current year. 

They exported power to the extent of 2,913.9 

MU to other Regions out of which 1,413.4 MU 

was exported to Northern Region and 1,488.1 

MU to Western Region. It imported 1,417.5 

MU power from Eastern Region and exported 

only 12.4 MU to it. The Talcher Stage-II 

Super Thermal Power Station (4X500 MW) in 

Eastern Region is dedicated power station for 

the Southern Region except for 200 MW to the 

home state of Orissa in ER. The power from 

this station and surplus power from ER flows 

over Talcher-Kolar HVDC bipole link with 

a capacity of 2,500 MW and HVDC backto-back 

link at Gazuwaka with a capacity 

of 1,000 MW and Balimela-Upper Sileru 

220kV S/C with a capacity of 130 MW. It is 

connected with Western Region through 1,000 

MW HVDC back to back link at Chandrapur. 

4.4.4 Eastern Regional Grid 

The Eastern Grid has an installed capacity 


16,654 MW thermal, 3,934 MW hydro and 227 

MW renewable energy sources. It had a peak 

load of 12,901 MW (ex-bus) during the year. 

The Eastern Grid faced an energy shortage of 

4.4% and a peaking shortage of 8.6% during 

the current year as compared to energy and 

peak shortages of 4.9% and 11.1% respectively 

during previous year. The Eastern Regional 

grid operated in synchronism with Western, 

Northern and North-Eastern Regional grids. 

Unallocated power to the tune of 400 MW from 

NTPC stations in Eastern Region and 65 MW 

power surrendered by DVC were allocated to 

the beneficiaries of other Regions in April, 2008. 

However, due to high demand of the states of 

Eastern Region, additional allocation of 9 MW 

was made to Jharkhand and 33 MW to Bihar 

on 01-11-2008 from Kahalgaon STPS Stage-II 

(Unit-1) and 9 MW to Jharkhand and 33 MW 

to Bihar on 08-01-2009 from Kahalgaon STPS 

Stage-II (Unit-2). As on 31-3-2009, 466 MW 

of power from the unallocated quota of Central 

Generating Stations in Eastern Region and 65 

MW power surrendered by DVC is allocated to 

States in Northern, Western, Southern and North 

East Regions. Southern Region received power 

through 1,000 MW HVDC back to back link at 

Gazuwaka. 

The Eastern Region was the highest 

exporter of power among all Regions, exporting 

a total of 13,570.7 MUs. It exported 8,161.0 

MUs to Northern Region, 3,236.6 MUs to 

Western Region, 1,417.5 MUs to Southern 

Region and 755.6 MUs to North Eastern Region. 

There were marginal imports from all Regions 

totaling to 95.2 MUs. Eastern Region is the only 

Region connected to all Regions. It is connected 

to Northern Region through Muzaffarpur - 

Gorahkpur 400 kV D/C line with TCSC, Patna 

– Balia 400 kV D/C line, Biharshariff – Balia 

400 kV D/C line, and bypassing of HVDC backto-back 

link at Sasaram to establish Sasaram – 

Allahabad/ Varanasi 400 kV D/C line, to Western 

Region through 220 kV triple circuit Korba 

– Budhipadar AC lines and Raipur- Rourkela 

400 kV D/C AC lines and Ranchi- Sipat 400 kV 

D/C line, to Southern Region through Talcher 

- Kolar HVDC bipole link and HVDC back-toback 

link at Gazuwaka and to North-Eastern 

Region through Bongaigaon – Malda 400 kV 

D/C lines and Birpara – Salakati 220 kV D/C 

lines. 

4.4.5 North-Eastern Regional Grid 

The North-Eastern Grid has an installed 

capacity of 2,256 MW as on 31-3-2009 

consisting of 969 MW thermal, 1,116 MW hydro 

and 171 MW renewable energy sources. It had 



a peak load of 1,820 MW (ex-bus) during the 

year. The North-Eastern Grid faced an energy 

shortage of 13.5% and a peaking shortage of 

25.4% during the current year as compared to 


respectively during the corresponding period 

last year mainly on account of transmission and 

distribution constraints. The North-Eastern Grid 

operated in synchronism with Northern Grid, 

Eastern Grid and Western Grid. North Eastern 

Regional Grid is connected directly only to the 

Eastern Regional Grid and any export of power 

to the other Regions has to be wheeled through 

the Eastern Regional Grid. The energy exported 

from North-Eastern Region to Northern 

Region, Western Region, Southern Region 

and Eastern Region was 383.0 MUs, 412.5 

MUs, 53.9 MUs and 24.8 MUs respectively. 

The total export from this Region to other 

Regions was 874.2 MUs. The power transfer 

from North-Eastern Region to Eastern Region 

is taking place over Bongaigaon – Malda 400 

kV D/C lines and Birpara – Salakati 220 kV 

D/C lines. 

4.5 Monitoring of Capacitor Installation 

Programme 

In order to obtain a proper voltage profile 

in the regional Grids, the capacitor requirement 

at regional level is assessed by respective 

Regional Power Committees (RPCs). The 

capacitor installation programme for the year 

is finalised in consultation with the constituents 

of the Region. The actual installation of shunt 

capacitors during the year 2008-2009 was 546.02 

MVAR, 20 MVAR and 7.2 MVAR in Northern, 

Western and Southern Regions respectively 

leaving a shortfall of 7290.58 MVAR as per the 

details given as Annexure–4B. The progress of 

capacitor installation in the country has been 

slow. The matter is being followed up by CEA 

and RPCs. Capacitors were not required to 

be installed in the Eastern and North-Eastern 

Regions, as there were no problems of low 

voltages in these regions. 

4.6 Power Exchange 

The Electricity Act, 2003 provides an 

enabling framework for accelerated and more 

efficient development of power sector. The Act 

seeks to encourage competition with appropriate 

regulatory intervention. Competition is expected 

to yield efficiency gain and in turn result in 

availability of quality supply of electricity to 

consumers at competitive cost. In the Act, trading 

is included as a distinct activity. 

An electricity trader requires a license 

for trading in electricity from the appropriate 

Electricity Regulatory Commission, i.e. from 

Central Electricity Regulatory Commission for 

inter-State trading of electricity and from the 

respective State Regulatory Commission for 

intra-State trading of electricity. The Appropriate 

Commission may specify the technical 

requirement, capital adequacy requirement and 

creditworthiness for being an electricity trader. 

Under the provision of granting license for 

inter-State trading of power, the CERC has as 

on February 2009 granted license to 43 power 

traders for inter-State trading of power. 

The Appropriate Commission endeavours 

to promote the development of a market 

(including trading) in power. As per Para 5.7.1 

of National Electricity Policy, it is proposed to 

sell a part of new generating capacities (Say 15% 

of capacity) to be sold outside long term PPAs to 

promote market development which would lead 

to reduction in tariff aimed to provide significant 

benefits to consumers. This would encourage 

short-term trading of power. 

In this regard, the National Electricity 

Policy also envisages the setting up of a Power 


65


Exchange on the lines of a stock exchange for 

efficient and transparent next day trading. Indian 

Energy Exchange Ltd (IEX) and Power Exchange 

India Ltd (PEX) commenced operations from 27 th 

June 2008 and 22 nd October 2008 respectively. 

The volume of electricity traded from the date 

of their inceptions till 31 st March 2009 by IEX 

and PEX are 2,616.17 MU and 149.36 MU 

respectively. 

4.7 Infrastructure of RPC Secretariats 

All the Regional Power Committees, 

except North Eastern Regional Power Committee 

(NERPC) at Shillong have their own office 

building and staff quarters. Land measuring 

10.5 acres was jointly purchased by NERPC and 

PGCIL at Shillong for office-cum-residential 

complexes of NERPC and NERLDC. Out of 

this, about 1.97 acres of land has been kept for 

office-cum-residential complex of NERPC, 

Shillong and 0.13 acres of land for common 

areas to be shared by NERPC, Shillong. Transfer 

of title of land from PGCIL to CEA/ NERPC 

was notified by the Revenue Department, Govt. 

of Meghalaya vide letter dated 20/4/2007. 

Revised SFC memo for estimated cost of 

Rs. 11.44 Crores has been approved by MoP vide 

their letter dated 28/01/2008. The construction 

work has been awarded to “M/s Infrastructural 

Development Consortium”, Shillong by CPWD, 

vide letter dated 26/2/2008. Regional Inspectorial 

Organisation (North East Region) Office would 

also be accommodated in the same building. The 

construction work of the office-cum-residential 

complex of NERPC is under progress and is 

likely to be completed during 2009-10. 

4.8 Power & Telecommunication 

Co-ordination Committee (PTCC) 

CEA continued to follow up cases for 

expeditious PTCC clearance of EHT transmission 

lines of voltages 220 kV and above through 

discussions with Bharat Sanchar Nigam Ltd. 

(BSNL), Railways and SEBs/Power Utilities. 

CEA also rendered assistance to the State Power 

Utilities in resolving complex PTCC cases of 

voltage level of 132 kV and below. 

88 th Central PTCC meeting was held in 

May 2008 at Bhubaneshwar and 89 th Central 

PTCC meeting was organized in January, 

2009 at Aurangabad (Maharashtra). The 

meetings were attended by officers upto the 

rank of Chief Engineer from SEBs/Power 

Utilities, Chief General Managers from 

Bharat Sanchar Nigam Ltd. (BSNL) and 

senior officers from Railways and Defence. 

In the meetings many contentious issues 

which are in the interest of Power Sector 

were discussed and some of the important 

decisions taken are as under: 

‣ The Central PTCC decided that the 

private parties who intend to erect EHT 

power lines should route their PTCC route 

proposals through Member power state 

transmission utility/ Central power utility/ 

SLPTCC of the concerned state. 

‣ The sub-committee formed for revision of 

PTCC manual was further strengthened 

with few more experienced officers who 

are well versed with the contents of the 

present PTCC manual. 

‣ A Protection / Re-Engineering Supervisory 

Sub-Committee has been formed to 

scrutinize the re-engineering estimates 

submitted by BSNL/Railways. The 

supervisory committee would also work to 

bring uniformity in the scope of equipment 

required for re-engineering and cost 

aspects too. 



‣ The Central PTCC agreed to the proposal 

from Director (Telecom), Railway Board 

for conducting a refresher training course 

on PTCC for the concerned officers from 

all the zones of the railways. The training 

shall be organized by the Railways at the 

Railway Training Institute, Secunderabad. 

During 2008-09, 106 new cases of power 

lines were received for PTCC clearance. A bar 

chart indicating the number of cases received 

for PTCC clearance during the last six financial 

years is given below: 

During 2008-09, CEA has sent Induced 

Voltage (IV) comments for 88 cases to DEs(T), 

PTCC, BSNL for issuing necessary route 

approvals. About 2300 ckm of 220 kV lines, 

about 5800 ckm of 400 kV lines and 1000 ckm 

of 765 kV lines were accorded PTCC clearance 

to enable Power Utilities to commission their 

lines on schedule. 

A bar chart indicating the circuit kilometers 

of 220kV, 400kV and 765kV transmission lines 

for which PTCC clearance was accorded during 

the last six years is shown below. 


67


It can be seen from the above data that the 

number of cases received for PTCC clearance 

have increased marginally but the overall circuit 

kilometers of the EHT lines has decreased. This 

is because this year more number of transmission 

lines cases received for PTCC clearance were 

LILO cases. 

4.8.1 Computerisation of PTCC 

In order to cut down the PTCC 

cases processing time, a proposal for the 

computerization of PTCC has been forwarded to 

Ministry of Power for sanction. The estimated 

cost of the scheme is Rs.1466 Lakhs. A budget 

provision of Rs.70 Lakhs has been kept for the 

year 2009-10 towards appointing the consultant. 

4.9 Establishment of Load Despatch & 

Telecommunication Facilities for 

Power Sector 

All the five Unified Load Despatch and 

Communication (ULDC) schemes have been 

implemented and are in operation. CEA has 

been providing technical input to the Group / 

Committee (USMG) created for the expansion 

and O&M of the RLDCs system. 

4.10 National Load Despatch Centre 

(NLDC) 

The scheme for establishment of 

National Load Despatch Centre (NLDC) 

having communication links with all the five 

Regional Load Despatch Centres (RLDCs) 

for data exchange has been commissioned and 

inaugurated on 25 th February, 2009. 

4.11 Frequency Allocation Co-ordination 

for Microwave and Power Line 

Carrier Communication(PLCC) 

CEA co-ordinates and follows up with 

Wireless Planning and Co-ordination (WPC) 

Wing of Department of Telecommunications 

(DoT) to achieve timely frequency allocation 

for PLCC system of new power transmission 

lines and VHF/ UHF / Microwave systems of 

power utilities. 

As per the WPC, the frequency band 2.3- 

2.4 GHz used for microwave communication in 

the ULDC schemes for Load Despatch systems 

is to be vacated. CEA has examined the case 

and have forwarded its comments to Ministry of 

Power for further necessary action. 

During the financial year 2008-09, 

frequency allocation for PLCC for 58 cases has 

been made. CEA intervened for early allocation 

for the cases of J&K, PGCIL, Adani Power, 

GSECL and others with WPC Wing of DoT for 

expediting the allocation of frequency for their 

new power lines. 

***** 



CHAPTER – 5 

HYDRO POWER DEVELOPMENT 

5.1 Hydro Potential and its Development 

The re-assessment studies of hydro-electric 

potential of the country, completed by Central 

Electricity Authority in 1987, have assessed the 

economically exploitable hydro power potential 

as 84044 MW at 60 % load factor. A total of 845 

hydro-electric schemes have been identified in 

the various basins. The hydro potential of 84,044 

MW at 60% load factor when fully developed 

would result in an installed capacity of about 

1,50,000 MW on the basis of probable average 

load factor. 

The basin-wise details of hydro electric 

potential development in terms of Installed 

Capacity are indicated in the table below. As 

on 31.03.2009, the hydro-electric schemes in 

operation account for only 22.34% and those 

under execution for 8.64 % of the total potential 

40000 

35000 

BASINWISE STATUS OF H.E. POTENTIAL DEVELOPMENT At 60% LF 

(As on 31.03.2008) 

34920 

Pot en t i al at 6 0 % L F 

30000 

25000 

20000 

15000 

10000 

5000 

0 

19988 

3929 

1677 

10715 

2781 

684 

2740 

1752 

233 

Indus Ganga Central Indian 

Rivers 

Basins 

6149 

3704 

41 

West flowing 

Rivers 

9532 

4265 

46 

East flowing 

Rivers 

856 

1461 

Brahmaputra 

Assessed Developed Under development 

in terms of installed capacity. Thus, the bulk of 

the potential (69.02%) remains to be developed. 

The re-assessment studies have also 

identified 56 sites for Pumped Storage Schemes 

(PSS) with probable total installation of about 

94,000 MW. At present, 11 Nos. Pumped Storage 

Projects having total installed capacity of 4809.60 

MW are under operation and one Pumped Storage 

project (1000 MW) is sanctioned and is being 

taken up for construction. 

In addition, the study for the assessment 

of small hydro potential has been completed in 

June, 1996 by CEA. 1512 small hydro-electric 

schemes with aggregate installed capacity of 

about 6782 MW on canal falls/ rivers have been 

identified. 


69


5.2 50,000 MW Hydro-Electric initiative 

Under the 50,000 MW Initiative, preparation 

of Preliminary Feasibility Reports (PFRs) of 162 

hydro-electric projects spreading in 16 states was 

taken up by CEA as nodal agency in the year 2003-04 

with CPSUs/State agencies as Consultants. CEA’s 

role included overall coordination, facilitating 

collection of data, and quality control by vetting 

conceptual planning, assessment of power benefits 

and selection of project parameters, evacuation 

of power and monitoring of works. National 

Hydro-Electric Power Corporation Ltd, WAPCOS, 

North-eastern Electric Power Corporation, Satluj 

Jal Vidyut Nigam Ltd and number of State Power 

Utilities were associated to complete these 

feasibility studies. The PFRs were completed in 

Sept., 2004 for all these projects with an installation 

of 47,930 MW. 

As a follow up of preparation of PFRs, 

it has been decided to take up implementation/ 

preparation of DPRs for attractive schemes 

selected from PFR schemes thereby providing a 

shelf of projects for execution in the near future. 

Out of 162 schemes (47930 MW) for which 

PFRs have been prepared, at first instance, 

based on their preliminary techno-economic 

analysis, 78 schemes (34020 MW) whose first 

year tariff works out below Rs. 2.50/kWh have 

been considered as low tariff H.E. schemes and 

have been selected for taking up of detailed 

survey & investigation and preparation of DPR/ 

implementation. The details of these schemes are 

enclosed at Annexure-5A. Out of these, action 

has been initiated for 77 schemes (33951MW) for 

S&I and preparation of DPRs by CPSUs/SPSUs 

/SEBs /IPPs. 

Out of these, DPRs of 19 schemes (7093 

MW) have already been prepared. DPRs for 

18 schemes (9659 MW) are scheduled to be 

prepared during 2009-10 and 2010-11. The work 

of preparation of DPRs of remaining 40 schemes 

(17199 MW) is held up due to proposed change in 

Agency /Allotment by State Govt., issues related 

to Environment & Forest Clearance and local 

agitation. These 77 schemes are expected to yield 

benefits during 12 th plan and beyond. 

5.3 Construction Monitoring of Hydro 

Projects 

The monitoring mechanism has been 

strengthened for timely completion and 

to achieve capacity addition targets of the 

sanctioned and on-going power projects in the 

country (Central, State and Private Sectors), 

Central Electricity Authority (CEA) has 

nominated a nodal officer for each project, 

both at the conception stage as well as during 

execution. The nodal officer keeps track of 

and facilitates resolution of problems which 

may delay the project by escalating the issues 

to appropriate levels for resolution. Regular 

visits were made by the officers, to the project 

sites for progress review and in this context, 

54 visits were made in the year 2008-09. In 

addition to above visits, review meetings 

are organized regularly and quarterly review 

meetings are held in CEA to discuss criticality 

of each project. Review meetings are held with 

project authorities for identifying bottlenecks 

and taking corrective measures. Meetings are 

also held with major equipment suppliers and 

other major contractors executing the major 

works of dam, head race tunnel, power house, 

etc. for solving the major constraints delaying 

the execution of the projects at project site/ 

their works. Efforts are being made to minimize 

contractual problems to avoid delays in project 

execution. Further, the expenditures incurred 

by the projects are being monitored to ensure 

that the physical progress is commensurate 

with the financial progress. 



5.4 Hydro Capacity Addition during 

2008-09 

Target hydro capacity addition for the 

year 2008-09 was 1097 MW and the capacity 

achieved against this target was 969 MW 

(about 88%) from 8 units of 4 projects all in 

State Sector. The main slippages in capacity 

additions were Priyadarshini Jurala (78MW), 

and Kuttiyadi Additional Extn. (50MW) in 

State Sector. Project-wise details are given at 

Annexure-5B. 

5.4.1 Hydro Capacity Addition Programme 


A hydro capacity addition of 845 MW 

(7 Projects, 18 Units) has been programmed 

comprising 252 MW in Central Sector, 301 MW 

in State Sector, and 292 MW in Private Sector. 

Project-wise details are given at Annexure-5C. 

5.4.2 Survey & Investigation of Hydro 

Projects 

In order to accelerate the pace of hydro 

development in the country, CEA provides 

assistance to various Central/State agencies 

in the matter of survey, investigation and 

preparation of DPRs of hydro projects. CEA 

has been monitoring the physical and financial 

progress of survey and investigation of all the 

hydro schemes. During the year, following 

works were handled in this regard: 

● The progress of Survey & Investigation works 

received from various SEB’s / Agencies was 

analysed and periodically updated. 

● The cost estimates for survey and 

investigation and preparation of feasibility 

report for Gyspa H. E. Project (300 MW) in 

Himachal Pradesh, submitted by HPSEB, 

was examined and recommendations sent to 

Ministry of Power. 

5.5 Power Project Planning & Optimization 

Studies 

During the year, the following Project Planning & 

Optimization Studies including Power Potential 

Studies were carried out: 

● Ken Betwa Link Canal Project( 2x30+3x6 

MW) in M.P/U.P and Power Chapter was 

prepared/ sent to NWDA for incorporation 

in the DPR being prepared by them. 

● Power Potential Studies and Cost Benefit 

analysis were examined for optimization of 

project parameters of Kulsi Multipurpose 

Project 70 MW in Assam. 

● Power Potential Studies were carried out 

for examining justification of Myntdu 

Stage-I extension project (1x42 MW) in 

Meghalaya. 

● Power Potential Studies for three H.E Projects 

namely Umngot Storage (Meghalaya), Ujh 

Multipurpose Project (J&K) and Kalez 

Khola (Sikkim). 

5.6 Studies and other Activities Related 

to Hydro Power Planning 

5.6.1 Review of Hydro Electric Potential and 

Basin-Wise Optimization Studies 

A proposal was prepared and sent to Ministry 

of Power for review of hydro-electric potential 

in the country and for carrying out basin-wise 

optimization studies for optimum development of 

hydro-electric potential in different River Basins 

of the country. 

5.6.2 Indus-Water Treaty Matters 

● In pursuant to decision taken in a Committee 

of Secretaries (CoS) meeting held on 

14.7.2008, a Committee was constituted 

on 8.10.2008 under the Chairmanship of 

Member (D&R), CWC to come out with a 

feasible site for the Bursar HE Storage Project 

for optimal utilization of the storage available 


71


● 

● 

to India under Indus Water Treaty, 1965. The 

Committee held two meetings in Dec., 2008 

and Feb., 2008 and recommended Hanzal site 

for locating the dam where storage available 

is of the order of 1.0 MAF. 

A proposal for investment by International 

Finance Corporation (IFC), a part of World 

Bank in New Bong Escape HE Project across 

Jhelum river in Pakistan, being implemented 

by Ranhill Laraib Energy Ltd. Co. was 

examined from the point of view of any 

adverse impact on existing/ on-going Hydro 

Projects located in Jhelum river in India and 

commented upon. 

Objections pertaining to Kishenganga 

raised by Pakistan Commission during 100 th 

Meeting of Permanent Indus Commission 

(PIC) were examined and replied to. 

5.6.3 Revision of Design Energy 

● Proposal for revision of design energy for 

Tehri St.-I H.E Project was finalized and is 

being put up for approval of the Authority. 

● Proposal for revision of design energy 

for Nathpa Jhakri H.E Project has been 

finalized and is being put up to Authority for 

approval. 

● OHPC proposal for review of design energy 

for five projects viz. Upper Kolab (320 

MW), Hirakud I & II (347.5 MW), Rengali 

(250MW), Balimela (360 MW) and Upper 

Indravati (600 MW) was examined and 

methodology adopted by OHPC for revised 

design energy was commented upon. 

● Examined proposal of NEEPCO for revision/ 

reassessment of design energy for Kopili and 

comments were forwarded. 

5.7 Advance action for Capacity Addition 

in the 12 th Plan and beyond 

As per the studies carried out by CEA to 

assess the requirement of additional capacity 

during the 12 th Plan (2012-17), to meet the all 

India peak demand and energy requirement at 

the end of 12 th Plan, a capacity addition of more 

than 100,000 MW in the 5 years period of 2012- 

17 would be required, out of which 20,000 MW 

is proposed to be added through hydro Projects. 

An exercise has been carried out in CEA to 

identify candidate Hydro Projects for inclusion 

in the 12 th Plan and beyond. A shelf of 109 

candidate projects aggregating to 30920 MW 

having higher level of confidence for realising 

benefits during 12 th Plan, based on their status 

of preparedness has been finalised. List of these 

schemes is given at Annexure-5D. A document 

titled ‘Hydro Development Plan for 12 th Five 

Year Plan (2012-2017) was also prepared in this 

regard and circulated to all concerned. It has 

been proposed that the concurrence of the hydro 

projects envisaged for commissioning during 12 th 

Plan should be obtained and orders for the main 

packages awarded by the developer during the 

11 th Plan itself. 

5.8 Co-operation with Neighbouring 

Countries 

‣ Draft agreement to be signed between 

India and Nepal regarding Pancheshwar 

Development Authority (PDA) for 

Development, Execution and Operation 

of Pancheshwar MPP was examined and 


‣ Examined proposal regarding Chinese 

participation in development of Hydro Power 

in Nepal and was commented upon and 

forwarded to Govt. of India. 

‣ A multi-disciplinary team of experts 

comprising CEA, CWC and WAPCOS 

visited 1200 MW Punatsangchhu-I HE 

Project site in April 2008 for finalizing and 

optimization of the project components. 



‣ A team of experts from Planning & Design 

divisions of CEA, CWC and WAPCOS visited 

Bhutan in connection with presentation on 

works progressed so far in respect of DPR 

of Punatsangchhu H.E. Project Stage-II (990 

MW). 

5.8.1 International Co-operation 

Prepared Note in connection with Bilateral 

Sectoral Cooperation between India & 

Myanmar in the field of power sector. 

Proposals to be posed to Govt. of Japan for 

JICA Assistance in 2009 were dealt with. 

5.9 Hydro Power Plants Performance & 

Operation Monitoring 

‣ Performance of 641 units in 208 Hydro 

Stations with aggregate Installed Capacity 

of 31003.00 MW was analyzed in respect of 

their outages & generation and report on the 

review of HE stations for the year 2007-08 

was finalized. 

‣ Mid term review of generation performance 

of hydro electric stations of the country for 

the year 2008-09 was carried out in Jan., 2009 

after withdrawal of South-West monsoon by 

interaction with SEBs, Power Deptts. and 

CPSUs. The generation targets were reviewed 

for the remaining part of the year 2008-09. 

‣ Month-wise/station-wise hydro generation 

targets for year 2009-10 were drawn in 

consultation with various utilities and 

tentatively fixed at 115468.00 MU which was 

about2.52 % lower than generation targets 

for the year 2008-09. Generation targets 

for the year 2009-10 have been considered 

for Stations of 25 MW and above, whereas 

during the year 2008-09, the generation 

targets were fixed for Stations above 3 MW 

capacity. 

‣ To accord recognition to Hydro Power 

Stations for their all round performance, 

performance data of HE Stations having 

Installed Capacity of 100 MW and above 

was analyzed and three HE Stations namely 

Baspa -II ( 3x100 MW), Bhira & Bhira PSS 

(6x25 MW + 1x150 MW) and Gerusoppa HE 

Station (4x60 MW), were recommended for 

National Award for best performance under 

“National Award for the year 2007-08 for 

Meritorious Performance in Power Sector”. 

5.9.1 Hydel Generation Performance 

during the year 2008-09 

The region wise summary of Hydel 

Generation performance in the country is as 

follows : 

Region Target MU Generation MU Deviation (+/ -) 

MU (%) 

Northern 52067.00 53026.00 959.00 (+)1.84 

Western 18616.00 13206.16 5409.84 (-) 29.06 

Southern 32345.00 32608.66 263.66 (+)0.82 

Eastern 10527.00 9600.36 926.64 (-)8.80 

N-Eastern 4895.00 4586.52 308.48 (-)6.30 

All India 118450.00 113027.70* 5422.30 (-)4.58 

* Tentative 

Against target of 118450 MU, the actual energy 

generation during the year 2008-09 was 113027.70 

MU which is 4.58 % less than the target. Hydel 

Generation has exceeded the target in Northern and 

Southern Regions, however it is less than the target 

in Western, Eastern and North Eastern Regions. 


73


5.10 Renovation and Modernization of 

Hydro Electric Power Projects 

5.10.1 R&M Phase-I Programme 

Recognising the benefits of the R&M 

programme, Govt. of India set up a National 

Committee in 1987 to formulate strategy on 

R&M of hydro power projects. Based on the 

recommendations of the National Committee and 

subsequent reviews, a programme for renovation, 

modernization and uprating of Hydro Power 

Stations was formulated by Central Electricity 

Authority in which 55 schemes were identified 

with an aggregate capacity of 9653 MW. The total 

cost of these schemes was estimated as Rs.1493 

Crores with expected benefit of 2531 MW. 

5.10.2 R&M Phase-II Programme 

As per the hydro policy of Govt. of India, 

declared in 1998, renovation & modernization 

of Hydro Power Plants accorded priority. 

Accordingly, 67 hydro R&M schemes having an 

aggregate capacity of 10318 MW were identified 

to be undertaken under Phase-II programme till 

the end of 10 th Plan i.e. by 31.03.2007 to accrue 

a benefit of 3685 MW at an estimated cost of Rs. 

2161Crores. 

5.11 National Perspective Plan 

CEA formulated National Perspective 

Plan for Hydro Power Stations in the year 2000 

and incorporated R&M proposals under phase- 

II programme alongwith left out schemes as 

recommended in phase-I programme of National 

Committee. The left out schemes were those 

which were either under implementation or were 

yet to be implemented. This Perspective Plan was 

for 9 th , 10 th and 11 th Plans for 117 schemes having 

an aggregate installed capacity of 19370 MW 

with benefit of 7755 MW at an estimated cost of 

Rs. 4654 crores. 

5.11.1 8 th , 9 th & 10 th Plan Achievements 

Under the hydro R&M programme, 65 (15 

in Central Sector and 50 in State Sector) hydro 

electric schemes (13 upto the 8 th Plan, 20 in the 

9 th Plan & 32 in the 10 th Plan) with an installed 

capacity of 10511 MW at a cost of Rs. 1726 

crores have been completed by the end of the 10 th 

Plan (i.e by 31 st March 2007) and have accrued 

a benefit of 2351 MW through Life Extension, 

Uprating and Restoration. 

5.11.2 11 th & 12 th Plan Programme 

For the 11 th Plan initially, a total of 62 

hydro R&M schemes are programmed with an 

installed capacity of about 11340 MW at an 

estimated cost of Rs. 4024 Crores to accrue 

a benefit of about 4392 MW through Life 

Extension, Uprating and Restoration. Based 

on discussion with State Electricity Boards/ 

State Electricity Utilities in April/May 2008, 

2 (two) schemes namely Jawahar Sagar (3x33 

MW) and Rana Pratap Sagar (4x43 MW) 

of Rajasthan Rajya Vidyut Utpadan Nigam 

Limited (RRVUNL) were dropped due to 

disagreement problems between Rajasthan and 

Madhya Pradesh. Further, 4 (Four) schemes viz. 

Hampi (2x9 MW +2x9MW), Machkund (3x17 

MW+3x21.25 MW) and Tungabhadra (2x9 MW 

+2x9MW) of APGENCO and Sholayar-I (2x35 

MW) of TNEB were shifted to 12 th Plan on the 

request of project authorities as the generating 

units are running satisfactorily. Thus 56 hydro 

R&M schemes having an installed capacity 

of about 10810 MW at an estimated cost of 

Rs. 4180 Crores were programmed to accrue 

a benefit of about 4099 MW through Life 

Extension, Uprating and Restoration. During 

2 years of 12 th Plan, 5 schemes (1 in Central 

Sector and 4 in State Sector) with an installed 



capacity of 854 MW at a cost of about Rs. 137 

Crores have been completed and have accrued 

a benefit of 50 MW through Life Extension 

& Uprating. The R&M works on balance 51 

ongoing schemes are under various stages of 

implementation. 

Further, 22 nos. of hydro electric schemes 

having an installed capacity of 2467 MW, 

which were programmed for completion during 

11 th Plan, have been shifted to12 th Plan, as 

RLA studies could not be completed or units 

are running comparatively satisfactorily. On 

completion of the R&M works of these schemes, 

there will be a benefit of 2246 MW through Life 

Extension and Uprating at an estimated cost of 

Rs.1066 Crores (provisional). 

5.12 Plan-wise summary of hydro R&M 

schemes (as on 31.03.2009) 

(i) Hydro R&M schemes completed up to 10 th 

Plan: 

Sl. 

No 

Plan Period Nos. of Projects Installed 

Central State Total Capacity 

Sector Sector 

(MW) 

1. Upto 8 th Plan 

Schemes completed 

2. 9 th Plan 


3. 10 th Plan 


(ii) Hydro R&M schemes planned during 11 th Plan: 

Estimated 

Cost (Rs. in 

Crs.) 

Actual 

Expenditure 

(Rs. in Crs.) 

Benefit 

(MW) 

2 11 13 1282 126 127 429 

8 12 20 4892 598 570 1093 

5 27 32 4337 1016 1029 829 

Sl.No Plan Period No. of Projects Installed 

Central State Total Capacity 

Sector Sector 

(MW) 

Estimated 

Cost 

(Rs. in Crs.) 

Actual 

Expenditure 

(Rs. in Crs.) 

Benefit 

(MW) 

(a) Programmed 10 46 56 10810 4180 595 4099 

(Revised) 

(b) Completed 1 4 5 854 157 137 50 

(c) Ongoing 5 21 26 7534 1730 447 2485 

(d) Under Tendering 3 8 11 1477 1145 10 493 

(e) 

Under DPR 

Finalisation 

1 7 8 500 452 1 

(Till date) 

(f) Under RLA Studies - 6 6 445 695 - 565 

iii) Hydro R&M schemes programmed for 12 th Plan: 

Sl.No Plan Period No. of Projects Installed 

Capacity 

Total (MW) 

Central 

Sector 

State 

Sector 

Estimated 

Cost 

(Rs. in Crs.) 

Actual 

Expenditure 

(Rs. in Crs.) 

(a) Programmed - 22 22 2467 1066 - 2246 

Note:- Installed capacity, Benefit & cost rounded to nearest zero. 

506 

Benefit 

(MW) 


75


5.13 Programme for the year 2008-09 

During the year 2008-09, it was programmed 

to complete 9 schemes having an installed capacity 

of 3009 MW. On completion of these schemes, 



Rs. 266 Crores. 

S. 

No 

Name of 

Scheme 

Inst.Cap. 

( MW) 

Agency 

1. Khodri,Ph.A 4x30 UJVNL 

2. Chilla, Ph.A 4x36 UJVNL 

3. Lower Sileru 4x115 APGENCO 

4. Upper Sileru 4x60 APGENCO 

5. SrisailamRB 7x110 APGENCO 

6. Koyna St.I &II 4x70 + 4x80 MSPGCL 

7. Koyna St-III 4x80 MSPGCL 

8. Lingnamakki 2x27.5 KPCL 

9. Sabarigiri 6x50 KSEB 

5.14 Achievement during the year 

2008-09 

The following three schemes of state sector 

having an aggregate installed capacity of about 

720 MW have been completed during the year 

2008-09 at an actual cost of Rs.101 crores. These 

schemes are for R&M benefits. 

Sl. 

No. 

Name of Scheme 

Inst.Cap. 

( MW) 

Agency 

1. Khodri, Phase-A (4x30) UJVNL 

2. Chilla, Phase-A (4x36) UJVNL 

3. Koyna Stage-I & II (4x70 + 

4x80) 

MSPGCL 

5.14.1 Reasons for Non-achievement of 

targets / completion during the year 

2008-09 

The reasons for non-achievement of target / 

delay in completion of programmed R&M hydro 

schemes are given as under:- 

(a) Due to delay in finalization of award of 

supply order 

‣ Koyna St. III (4x80 MW), MSPGCL 

‣ Lingnamakki (2x27.5 MW), KPCL 

(b) Due to increase in scope of work. 

‣ Lower Sileru(4x115 MW), APGENCO 

‣ Upper Sileru (4x60 MW), APGENCO 

‣ Srisailam (7x110 MW), APGENCO 

(c) Due to accident in Unit-4 of Sabirigiri Power 

Station, the scheme at Sl. No. 9 of clause 5.13 

above Sabrigiri (6x50 MW) KSEB is now 

shifted for completion during 2010-11. 

5.15 Miscellaneous works undertaken/ 

completed 

(i) 

Enquiry Committee for damage of 50 MW 

generator of Sabirigiri HEP (Kerala)- 

An enquiry committee was formed under 

the Chairmanship of C.E.(HE&RM) to find 

the reasons for damage to generating unit 

of Sabirgiri HEP. The committee submitted 

the report to KSEB identifying the causes of 

damages of Unit. 

(ii) Renovation and Modernisation of H.E. 

Projects under Bilateral programme 

i. Ministry of External Affairs, Govt. of India 

has requested CEA to vet the cost estimates 

prepared by a consortium of BHEL and 

NHPC for VARZOB-I Hydro Electric Plant 

(2x3.67 MW) to be uprated to (2x5 MW), 

Tajikistan for Renovation Modernization and 

uprating. CEA shall be vetting the bills for 

payment of the above works which shall be 

raised by BHEL and NHPC. 

ii. CEA on the request of Ministry of External 

Affairs, Govt. of India vetted the cost 

estimates prepared by a consortium of BHEL 

and NHPC for rehabilitation of Devighat 

Hydro Electric Project (3x5MW), Nepal. 



(iii) Renovation and Modernisation of 

Umium-II H. E. Project 

CEA assisted MeSEB in finalization of 

revised qualifying requirements and tender 

documents for early completion of R&M 

works of the above project. Based on the 

inputs of CEA, MeSEB issued the Notice 

Inviting Tender (NIT) and award of works 

by MeSEB is under progress. 

(iv) A Team of officers from CEA alongwith 

officers of CWC & CWMRS have visited 

the Khandong H. E. Power Station (2x25 

MW) of NEEPCO for assessing the damage 

of under water parts due to acidic water. 

(v) Other works : 

● Report of Technical Expert Group on 

proposed Brahmaputra Water Diversion 

by China was prepared in association with 

MoP, MoWR/ CWC, MEA, MoEF, MoSRT, 

Govt. of Arunachal Pradesh as desired by 

Committee of Secretaries. 

● The basin-wise proposal for review of 

hydro potential of HE Project in J&K as 

prepared by JKSPDC was examined and 


● A sub-group consisting of representatives of 

CEA, MEA, NHPC and NTPC was formed 

by the Interministerial Working Group to 

work out tariff model for hydro projects in 

Bhutan. The report of the subgroup has since 

been submitted and approved by the Working 

Group of Planning Commission. 

● Revised Preliminary Ranking study for HE 

Projects in J&K was carried out. 

● The proposal of GMR Energy Ltd. for Talong 

(Londa) HE Project in Arunachal Pradesh 

was examined and commented upon. 

● Memo regarding enhancement of capacity 

of hydel channel and generating units 

at Shahpurkandi Project in Punjab were 

examined and commented upon. 

● 

● 

● 

● 

Draft Standards/ Manuals/ Guidelines 

for small Hydro Development prepared 

by IIT, Roorkee was examined and 


Draft Chapter on Assessment of power 

potential and optimization of installed 

capacity in connection with preparation of 

Manual as “Development of Small Hydro 

Electric Project” by CBIP was examined and 


Dam Safety Act, 2008 was examined and 


Examined Policy Paper “Integrated 

Water Management: Policy and Actions” 

prepared by Planning Commission and 


5.16 Programme for the year 2009-10 

During the year 2009-10, it is programmed to 

complete 12 schemes having an installed capacity 

of 4942 MW. On completion of these schemes, 



about Rs. 241 crores (till date actual expenditure 

of Rs. 103 crores has been incurred). 

S. 

No. 


Inst .Cap. 

MW 

Agency 

1. Dehar Phase-A 6x165 BBMB 

2. Dehar Phase-B 6x165 BBMB 

3. Lower Sileru 4x115 APGENCO 

4. Upper Sileru 4x60 APGENCO 

5. Srisailam RB 7x110 APGENCO 

6. Nagjhari, U1 to U6 (3x150 + KPCL 

3x135) 

7. Shravathy, Ph. B 10x 103.5 KPCL 

8. Supa 2x50 KPCL 

9. Lingnamakki 2x27.5 KPCL 

10. Jaldhaka St. I 3x9 WBSEB 

11. Koyna St-III 4x80 MSPGCL 

12. Loktak 3x30 NHPC 


77


5.17 Concurrence of CEA to Hydro Electric 

Schemes 

After the enactment of The Electricity 

Act, 2003 and its coming into force w.e.f. 10 th 

June, 2003, the Central Electricity Authority 

is required to accord concurrence to Hydro 

Generation Schemes estimated to involve a capital 

expenditure exceeding such sum as may be fixed 

by the Central Government from time to time, as 

per provisions of Section 8 of this Act. 

The Government of India vide their 

Notification No.S.O. 550(E) dated 18 th April, 

2006 have fixed the following limits of capital 

expenditure for the Hydro Power Development 

Schemes exceeding which the concurrence of 

Central Electricity Authority is required:- 

1. Rs.2500 Crores provided that: 

(a) Scheme is included in the National 

Electricity Plan(NEP) as notified by the 

Central Electricity Authority under subsection(4) 

of Section 3 of The Electricity 

Act, 2003 and the same conforms to the 

capacity and type (run-of-river/storage) 

as mentioned in NEP; and 

(b) The site for setting up hydro generating 

station has been allocated through 

the transparent process of bidding in 

accordance with the guidelines issued by 

the Central Government under Section 

63 of The Electricity Act, 2003. 

2. Rs.500 Crores for any other scheme not 

covered by clauses (a) & (b) above. 

5.17.1 Techno-Economic Appraisal/ 

Concurrence of Hydro Schemes 

During the year 2008-09, CEA had 

appraised and accorded concurrence to 04 Nos. 

Hydro Generation schemes aggregating to 

860 MW capacity with an estimated financial 

investment of Rs. 4020.47 Crores. 

5.17.2 Reduction in Cost of Hydro Power 

Generation Projects 

It has been observed that in most of the 

cases, the cost estimates indicated by the project 

proponents in their Detailed Project Reports 

(DPRs) were on the higher side due to various 

reasons. On receipt of the DPRs, the same 

were thoroughly scrutinized by the various 

appraisal divisions of CEA & CWC/GSI before 

the proposals were considered by CEA for its 

concurrence. Review meetings were convened 

from time to time by Member (H) CEA, with 

the project developers and Chief Engineers of 

Appraisal divisions of CEA, CWC and GSI in 

order to sort out the outstanding issues/ remove 

bottlenecks in the DPRs with the objective of 

minimizing the time for appraisal process and 

optimizing the proposed capital cost. 

During the year 2008-09, four (04) hydro 

generation schemes aggregating to 860 MW capacity 

were accorded concurrence and net reduction in 

estimated cost achieved for these projects worked 

out to Rs 423.15 crores (about 9.52%) in hard cost 

as detailed in Annexure-5E. 

Karcham Wangtoo Projectdam Complex – Concreting In Progress 

***** 



CHAPTER – 6 

THERMAL POWER DEVELOPMENT 

6.1 Selection of sites for Thermal Power 

Projects 

In the context of the need to set up 

additional thermal power stations to meet the 

power requirements of the country up to the year 

2012 and beyond, CEA has in September, 2001 

constituted a committee under the Chairmanship 

of Member (Thermal) and consisting of members 

from different Ministries/ Deptts./ SEBs etc. for 

selection of sites for large coastal/Pit head and 

other Thermal Power Stations. As the process 

of selection of sites is of continuous nature, the 

above mentioned Committee has been converted 

into a Standing Committee. Teams consisting 

of the members of the Committee from CEA, 

Planning Commission, MoE&F, Central Mine 

Planning & Design Institute (CMPDI), Railways 

etc. are being constituted for visits from time to 

time, the sites tentatively identified by the State 

agencies and National Remote Sensing Agency 

(NRSA). These teams also interact with various 

States/Central departments for assessing the 

availability of various inputs required for setting 

up of Thermal Power Plants like land, water, fuel 

etc. 

In order to derive benefits of economy of 

scale, a need has been felt to identify large sites near 

pitheads and coast areas where big capacity plants 

say 3000- 5000 MW can be set up. Keeping this 

objective in mind, CEA awarded various studies 

for identification of large pithead and coastal 

sites using satellite mapping through remote 

sensing. CEA also awarded study to CMPDI 

for identification of sites near load centres using 

satellite mapping through remote sensing. Based 

on the reports of CMPDI, NRSA and site visits 

of the Site Selection Committee, a large shelf of 

potential sites has been created. Many sites from 

this shelf have been identified for benefits during 

the 11 th Plan. The reports of CMPDI & NRSA 

have been forwarded to concerned State Govts 

/ NTPC for development of the identified sites. 

The sites for Ultra Mega Power Projects (UMPP) 

have been identified from the shelf of sites created 

under the scheme. The NRSA reports for coastal 

sites have also been given to the site selection 

committee of Nuclear Power Corporation; who 

are in the process of identifying coastal sites for 

new Nuclear Power Plants. 

6.2 Setting up of Ultra Mega Power 

Projects (UMPPs) 

The Ministry of Power has launched an 

initiative for development of coal-based Ultra 

Mega Power Projects (UMPPs) in India, each with 

a capacity of 4,000 MW or above. These projects 

will be awarded to developers on the basis of 

tariff-based competitive bidding. To facilitate the 

tie-ups of inputs and clearances, project-specific 

shell companies have been set up as wholly owned 

subsidiaries of the Power Finance Corporation Ltd. 

(PFC). These companies undertake preliminary 

studies and obtain necessary clearances including 

water, land, fuel, power off take tie-up etc. prior 

to award of the project to the successful bidder. 

Originally, nine sites had been identified by 

CEA in nine States for the proposed UMPPs. These 

include four pithead sites, one each in Chhattisgarh, 

Jharkhand, Madhya Pradesh and Orissa, and five 

coastal sites, one each in Andhra Pradesh, Gujarat, 

Karnataka, Maharashtra and Tamil Nadu. It is 

proposed to set up pithead projects as integrated 

projects with corresponding captive coal mines. 


79


On the request of Ministry of Power, Ministry of 

Coal has already allocated / earmarked captive 

coal mining block(s) for Sasan UMPP in Madhya 

Pradesh, for Orissa UMPP, for Tilaiya UMPP in 

Jharkhand and for Chhattisgarh UMPP. For the 

coastal projects, imported coal shall be used. The 

projects are to be developed with a view to lower 

the cost of power to consumers. These projects, 

adopting supercritical technology to reduce 

emissions, would be environment-friendly. A time 

bound action plan for preparation of project report, 

tie-up of various inputs/clearances, appointment 

of consultants, preparation of RFQ/RFP is being 

followed. 

The bidding process in respect of Sasan, 

Mundra and Krishnapatnam UMPP has been 

completed. M/s Tata Power has been awarded 

the Mundra Project at levelised tarrif of Rs. 

2.26 per kWh. M/s Reliance Power Ltd. has been 

awarded Sasan and Krishnapatnam UMPPs at 

levelised tarrif of Rs.1.19616 per kWh and Rs.2.33 

per kWh respectively. The respective Special 

Purpose Vehicles (SPVs) of Sasan, Mundra and 

Krishnapatnam UMPPs have been transferred 

to the successful bidders. These projects are at 

different stages of development/construction. Joint 

Monitoring Committees under the Chairmanship 

of Member (Thermal) have been constituted to 

monitor the progress of the projects. The bidding 

process for 4 th UMPP namely, Tilaiya UMPP (4000 

MW) have been completed by the Special Purpose 

Vehicle i.e. Jharkhand Integrated Power Ltd. and 

LOI has been placed on M/s Reliance Power Ltd. 

in February, 2009. 

The site for fifth UMPP in Tamil Nadu 

has been finalized in consultation with the State 

Govt. and the Special Purpose Vehicle i.e. Coastal 

Tamil Nadu Power Ltd. has initiated feasibility 

studies. After completion of feasibility studies, 

bidding process for Tamil Nadu UMPP shall be 

initiated. The development of other four projects 

is contingent upon the various clearances from 

the respective State Governments. 

In addition to nine UMPPs originally identified, 

few more UMPPs are proposed as per details 

given below: 

‣ Two Additional UMPPs in Orissa- 4000 MW 

each 

‣ Second UMPP in Gujarat- 4000 MW 

‣ Second UMPP in Andhra Pradesh- 

4000MW 

Deen Bandhu Chhotu Ram Thermal Power Station, Yamuna Nagar (300 MW), Haryana 



The sites for the additional UMMPs are yet 

to be finalized. 

6.3 Private Sector Participation 

The response to the private sector 

participation has been encouraging. A thermal 

capacity of 17,626 MW is proposed during 11 th 

Plan under private sector. Out of this, a capacity 

of 1382 MW has been commissioned and a 

capacity of 16243 MW is under construction. 

Further a total of 106 projects totaling to 

94849 MW were recommended by Standing 

Committee of CEA for accord of coal linkage 

to MoP. Out of these, 36 nos. projects totaling 

to 25015 MW were granted LOA by SLC (LT) 

in the meeting held on 12.11.2008. 

Further, many utilities in states like 

Haryana, Punjab, Madhya Pradesh, Uttar Pradesh, 

Chhattisgarh, Maharashtra, Karnataka have 

proposed setting up of Thermal Power Projects 

through Tariff based Competitive Bidding 

(Case–II) route. This will encourage private 

sector participation in Power Sector. Details of 

power projects proposed through Tariff based 

Competitive Bidding (Case –II) route totaling to 

22,390 MW are given in Annexure- 6A. 

6.4 Construction Monitoring of Thermal 

Power Projects 

CEA is closely monitoring the progress of 

various constructional activities of thermal power 

projects under execution in the country for timely 

commissioning. Regular visits are made by CEA 

officers to the sites for assessing the progress 

of various construction activities and rendering 

necessary advice/assistance in resolving the 

problems being faced by the project authorities 

to meet the schedule of commissioning. Review 

Meetings are held in CEA with project authorities, 

main plant & equipment manufacturers and other 

equipment suppliers to review the progress. 

Monitoring mechanism in the CEA has been 

strengthened and Nodal Officers have been 

nominated for each project for close monitoring 

of the progress of a project. The major constraints 

in timely achievement of various milestones are 

identified and taken up at various levels in MoP/ 

State Govt. /Project authorities to resolve the 

issues. 

6.5 Thermal capacity addition programme 


During the year 2008-09, thermal capacity 

of 2485 MW was added against a capacity 

addition programme of 9304 MW. The details 

of the projects programmed/ commissioned 

during the year are given at Annexure-6B. The 

major reasons for slippages of commissioning 

of projects programmed during 2008-09 are 

given hereunder: 

(a) Delay in placement of orders – mainly civil 

works & Balance of Plants (BOPs). 

(b) Delay and non-sequential supply of material 

for main plant and BOPs. 

(c) Shortage of skilled manpower for erection 

and commissioning. 

(d) Contractual dispute between project developer 

and contractor and their sub-vendors /subcontractors. 

(e) Inadequate deployment of construction 

machinery 

(f) Shortage of fuel (Gas & Nuclear) 

(g) Delay in land acquisition 

(h) Delay in clearance / investment decision 

(i) Delay in environmental clearance. 

(j) Law and order problems. 

6.5.1 Thermal capacity addition programme 


As per the latest assessment, 13002 MW 

thermal capacity is expected to be added during 

2009-10. Details are shown in Annexure-6C. 


81


6.5.2 Achievement of Commercial Operation 

of Newly Commissioned Units 

After synchronization of the units, the status 

of completion of pending works is also monitored 

and follow-up action taken for early commercial 

operation of the units. Out of 10 thermal units 

commissioned during 2008-09, 6 Nos with a 

total capacity of 1392 MW has been declared on 

commercial operation. 

6.6 Thermal Technology Development 

6.6.1 Supercritical Technology 

CEA has been actively associated in 

developing road map for introduction of new 

technologies for thermal power generation. 

At present, the largest thermal unit size 

in operation is 500MW and a few units of 

600MW are under construction with sub-critical 

steam parameters. CEA has been facilitating 

adoption of higher size units with supercritical 

technology. Some of the supercritical units are 

under construction. These include six (6) Nos. 

660 MW units of NTPC and two (2) Nos. 800 

MW units of APPDCL. Four (4) Nos. Ultra 

Mega Power Projects, each of 4000 MW which 

have been awarded, would also be deploying 

supercritical technology. Initial supercritical 

units were designed with parameters of 247kg/ 

cm 2 , 537/565 0 C. Now higher parameters of 247 

kg/cm 2 , 565/593 0 C are being envisaged. 

In 12 th Plan, supercritical units are likely 

to constitute a majority of coal based capacity 

addition. Efforts have been made to attract 

international manufacturers to set up manufacturing 

facilities for Supercritical units in India so as to 

create indigenous manufacturing capability. As 

a result, four joint venture companies have been/ 

are being set between international manufacturers 

and Indian Companies for manufacturing 

supercritical boilers/ TG in the country. To kick 

start the new joint ventures, bulk tendering of 11 

Nos. 660 MW supercritical units of NTPC and 

DVC, is under consideration through International 

Competitive Bidding (ICB) with the mandatory 

condition that the successful bidders would have 

to set up manufacturing facilities in India as per 

phased manufacturing programme (PMP) being 

specified in the bid documents. 

6.7 Standard Technical Specification for 

500 MW Units 

Standard technical specification of main 

plant package of sub-critical thermal power 

project of 2x500 MW or above was prepared by 

CEA with participation from BHEL, NTPC and 

other utilities. The document covers scope, design 

criteria, equipment features, quality assurance 

plan, performance guarantee tests and spares 

etc. for steam generator, turbine generator along 

with their auxiliaries and associated electrical, 

C&I and civil works. The standard specification 

was got published and sent to concerned State 

Governments and Power Utilities across the 

country for their reference and guidance. Soft 

copy of the standard specification has also been 

uploaded on CEA web site. The adoption of 

standard specification will help in reducing the 

time for design & engineering and manufacturing 

of equipments, thus facilitating compressing of 

the execution schedule of the thermal projects. 

6.8 Recommendation to CERC regarding 

Operation Norms for Coal and Gas 

based Power Plant. 

As per the Tariff Policy, the Central 

Electricity Regulatory Commission is required 

to notify operating norms for generation and 

transmission in consultation with the Central 

Electricity Authority. Accordingly, CEA has 

furnished recommendations to CERC for 

operation norms of coal and gas based power 



plants to be applicable for the period commencing 

from April, 2009 onwards. 

6.9 Important activities 

Following activities were also undertaken 

in Thermal Wing of CEA: 

1. Committee to study design features of boilers 

sourced from Chinese manufacturers. 

2. Committee to suggest methodology for 

specific energy targets for power sector for 

Progress, Achieve & Trade (PAT) scheme 

under National Mission for Enhanced Energy 

Efficiency. 

3. Preparation of report on High Concentration 

Slurry of Ash from Thermal Station. 

4. Certification of goods required for UMPP for 

grant of Deemed Export benefit. 

6.10 Renovation & Modernisation of 

Thermal Power Stations 

Renovation and Modernisation (R&M) and 

Life Extension (LE) of an existing old power 

station provides an opportunity to get additional 

generation at low cost and short gestation period. 

Besides generation improvement, it results 

in improvement of environmental emissions 

and improvement in availability, safety and 

reliability. 

6.10.1 R&M (Phase-I) Programme 

R&M programme was initiated in 1984 as 

a centrally sponsored programme for 34 thermal 

power stations covering 163 thermal units in 

the country. The programme was successfully 

completed in the year 1992 and an additional 

generation of about 10,000 MU/ annum was 

achieved. 

6.10.2 R&M (Phase-II) Programme 

The Phase-II R&M programme for 44 

thermal power stations was taken up in the year 

1990-91. Power Finance Corporation (PFC) 

was to provide loan assistance to the State 

Electricity Boards (SEBs) for the R&M works. 

However, this programme could not progress 

as per schedule mainly due to non-availability 

of funds and poor financial conditions of State 

Electricity Boards (SEBs). 

The R&M programme continued to be 

implemented during 8 th , 9 th and 10 th Plan periods 

but met with limited success due to various reasons 

such as non-availability of units for shut down, 

delayed supply of materials, fund constraint, lack 

of agencies to undertake R&M works etc. Certain 

strategic initiatives such as facilitating wider 

participation of equipment suppliers / executing 

agencies, incentivise for upgradation of plant 

performance through R&M investment technoeconomically 

are needed. 

6.11.1 11 th Plan Programme 

Based on discussions with the State and 

Central power utilities, it was decided that during 

the 11 th Plan, 53 units (7318 MW) out of which 

33 units (4524 MW) in state sector and 20 units 

(2794 MW) in central sector would be taken up 

for life extension programme. Similarly for R&M 

works, a total number of 76 units (18965 MW) 

out of which 27 units (6015 MW) in state sector 

and 49 units (12950 MW) in central sector have 

been identified for implementation during the 11 th 

Plan. 

During the 11 th Plan period upto March 

2009, life extension works on Ukai- unit 1 (120 

MW), Panipat unit -1 (110 MW), Obra unit-2 (40 

MW) and partial LE works on unit- 6 (94 MW) 

of Obra TPS & unit 5 (60 MW) of Harduaganj 

TPS have been completed. Similarly, R&M works 

on 18 units (4350 MW) in state sector have been 

completed so far. Works on another 5 units in state 

sector (465 MW) and 40 units in central sector 


83


(38 units of NTPC and 2 units of DVC) of total 

capacity 9980 MW are in progress. 

The brief details of the 11 th Plan programme 

are shown as under : 

Particulars of works 

L.E. 

Works 

R&M 

Works 

No. of TPS 

No. of Units 

Capacity (MW) 

Estimated cost 

(Rs. Crores) 

Expected Benefits after 

completion of works 

Additional 

Generation (MU/ 

annum) 

Life Extension 

Works completed upto 

31-3-2009. 

no. of units (MW) 

23 53 7318 12433 7650 15 Years 5 (424 MW) 

21 76 18965 4500 4250 - 18 

(4350 MW) 

6.11.2 F u t u r e V i s i o n f o r R & M 

Programme 

So far, R&M activities were confined to 

old, small size units to sustain their operation, 

improve plant availability and extend their 

operating life. However, such units are highly 

inefficient and beset with various operational 

problems. It is aimed to gradually decommission 

such units. 

Today, 200/210/250MW/300MW and 500 

MW units (61655 MW) consisting of 81% of coal/ 

lignite based installed capacity form the backbone 

of Indian Power Sector. A large number of 200/210 

MW machines and few 500 MW machines are in 

operation for 15-25 years or more. Such machines 

through efficiency integrated R&M provide a 

good opportunity for performance enhancement 

through technology intensive R&M. Plant specific 

energy audit studies and techno-economic 

analysis are proposed to be carried out for defining 

& implementation of efficiency integrated R&M/ 

LE scheme. At present, three power stations viz., 

Bokaro ‘B’ TPS (3x210MW), Kolaghat TPS 

(3x210MW) and Nasik TPS Unit-3 (1x210MW) 

have been identified for efficiency integrated 

R&M study through bilateral cooperation with 

German Government. Contract has been awarded 

for preparation of Feasibility Study for all the 

above units. Further, few units such as Bandel TPS 

Unit-5 (210MW), Koradi TPS Unit-1 (210MW) 

and Panipat TPS (2x110MW) have also been 

identified for efficiency integrated R&M through 

World Bank assistance. NIT for main plant 

package for Bandel TPS Unit-5 has been floated. 

The Energy Efficient R&M programme through 

external assistance is intended to be taken up in 

few more units also. The potential units have been 

identified which may be taken up during 12 th Plan 

and beyond. 

The station-wise details of units tentatively 

identified for the Energy Efficient R&M are given 

in Annexure-6D. 

6.11.3 Technical assistance to CEA by the 

World Bank for the Energy Efficient 

R&M 

The World Bank is providing technical 

assistance of US $ 1.1 million as a part of GEF 

grant under Coal Fired Generation Rehabilitation 



Project to CEA for addressing the barriers to Energy 

Efficient R&M in India. The scheme would be 

implemented through appointment of consultants for 

carrying out studies related to reduction of barriers 

to R&M interventions in India, developing market 

for implementations and strengthening institutional 

capacity at CEA in the field of R&M. 

6.12 “ P a r t n e r s h i p i n E x c e l l e n c e ” 

Programme 

‘Partnership in Excellence (PIE)’ was 

launched by Ministry of Power in August, 2005 

for an initial period of 2 years (i.e. upto Aug. 

2007) to improve performance of such stations 

which were running at PLF much below 60%. 

CEA identified thermal stations which were 

running at PLF below 60%. NTPC was chosen 

as partner in 16 thermal power stations and Tata 

Power was selected in case of Dhuvaran TPS. 

Four stations decided to take self-improvement 

measures. The PIE programme has been 

concluded in all identified thermal power 

stations by June 2008. 

There has been improvement in most of 

the stations with significant improvement in the 

following: 

Sl. 

No. 

Name of the plant / 

utility 

Capacity under 

PIE Programme 

PLF before PIE 

Programme (Apr-Sep 2005) 

PLF after PIE Programme 

(2007-08) 

1. Bokaro ‘B / DVC 630 MW 45.5 % 70.9 % 

2. Chandrapura / DVC 390 MW 58.8 % 69.4 % 

3. Rajghat / IPGCL 135 MW 42.5 % 75.5 % 

4. Ennore / TNEB 280 MW 22.0 % 59.3 % 

5. Dhuvaran / GSECL 280 MW 27.0 % 71.0 % 

6. Kutch lignite / GSECL 215 MW 28.3 % 72.9 % 

6.13 Fly Ash Generation & Utilization 

6.13.1 Fly Ash Utilisation 

At present, the installed capacity of coal/ 

lignite based TPS in the country is about 77127 

MW as on 28.2.09 and the figure is likely to 

increase with coming up of a large thermal 

capacity during 11 th Plan. The total ash being 

generated by thermal power stations pertaining 

to Power Utilities, works out to be 124 million 

tonnes per annum. It is estimated that from a total 

thermal capacity (coal/lignite) based TPS, by end 

of 11 th Plan, the ash generated in the form of fly 

ash (80-90%) and bottom ash (10-20%) would 

be of the order of 193 million tonnes per annum 

considering 38% ash content in coal as an average 

and at 80% PLF. On economic considerations 

coal/lignite based TPS are preferred to be located 

near the source of coal/lignite i.e. pit head, ash 

generated is to be utilized in various ways by 

locating industries in the vicinity depending 

upon the characteristics and other engineering 

properties of the ash. The beneficiation of coal 

by reduction in the percentage ash content and by 

blending with imported coal will reduce the total 

quantity of ash generation. 

Presently, the ash based products are 

at developmental stage and there is a need to 

increase its use progressively. Some of the areas 

of fly ash utilization are as under : 

(i) Brick/Block/Tiles manufacturing 

(ii) Cement manufacturing 

(iii) Roads and embankment construction 

(iv) Structural fill for reclaiming low lying areas 

(v) Mine- filling 

(vi) Agriculture, Forestry and Wasteland 

development 


85


(vii) Part replacement of cement in mortar, 

concrete and ready mix concrete 

(viii) Hydraulic structure (Roller compacted 

concrete) 

(ix) Ash Dyke Raising 

(x) Building components – Mortar, Concrete, 

Concrete Hollow Blocks, Aerated Concrete 

Blocks etc. 

(xi) Other medium and high value added products 

(ceramic tiles, wood, paints) pavement 

blocks, light weight aggregate, extraction 

of alumina, Cenospheres, etc. 

As mentioned above, by the end of 2012, 

the ash likely to be generated from coal/lignite 

thermal capacity shall be of the order of 193 

million tonnes per annum, A number of measures 

are being taken to encourage various sectors to 

consume fly ash. The targets of ash utilization are 

primarily governed by the MoE&F Notification 

dated 14 th September, 1999 and its amendment 

notification dated 27 th August, 2003 as well as 

Hon’ble High Court of Delhi directions vide its 

judgments dated 4 th December, 2002, 10 th March, 

2004 as well as 5 th August, 2004. 

The existing thermal power plants as on 

September, 1999 are to achieve ash utilization 

level of 100% in a phased manner by 2013-14 

in accordance with 15 year action plan as per 

notification dated 14 th September, 1999 and 

with effect from the date of publication of the 

notification. The new power plant commissioned 

subsequent to September, 1999 are to achieve ash 

utilization level of 100% in a phased manner as 

per 9 year action plan and with effect from the 

date of publication of the notification dated 14 th 

September, 1999. Besides, MoE&F has also issued 

an Amendment Notification dated 27 th August, 

2003 and has extended the scope of ash utilization 

by various construction agencies by stipulating 

specific targets for those within 50 km and 50 to 

100 km radial distance of the location of thermal 

power plant. Construction agencies located within 

50 km are to achieve ash utilization level targets of 

100% up to August, 2005 and those located from 

50 to 100 km distance are to achieve ash utilization 

level targets of 100% by Aug. 2007. 

A draft Notification No. SO: 1574 dated 6 th Nov’ 

2008 was issued by MoE&F on utilization of 

fly ash generated from thermal power stations. 

CEA is involved in conveying the comment of 

Power Sector on the draft notification and its 

finalization. 

6.13.2 Monitoring of Fly Ash Generation 

and Utilization 

CEA continues to monitor the fly ash 

generation and ash utilization of coal/lignite based 

thermal power plants pertaining to power utilities 

of the Centre and the States. Following activities 

were carried out during the year : 

(a) The data pertaining to 2008-09 (from April, 

08 to Sept., 08) was sought from 85 coal/ 

lignite based power plants pertaining to 

29 power utilities in 17 States. The overall 

percentage of ash utilization during the first 

half year (2008-09) has been worked out to 

be 53.68 %. The ash utilization in various 

modes during the 1 st half of 2008-09 has been 

compiled (see Chart-I). 

(b) The progressive ash utilization data up to 

the year 2007-08 has been compiled (see 

Graph-II). The ash utilization in various 

modes of ash utilization during 2007-08 was 

compiled (see Chart-III). State-wise, power 

utility wise and region wise abstract of the 

data has been compiled. 

(c) A report on Fly ash generation and 

utilization data of 85 as utilities TPS wise, 

State wise, Region-wise, Sector-wise 

for the year 2007-08 was prepared. The 

actual ash generated was 116.94 MT and 

ash utilized was 61.97 MT and the overall 

percentage was 53. 



Chart-I 

Fly Ash Utilization in various Modes 

during 2008- 09(Half Yearly upto september 2009) 

(Mode, Quantity Utilized in million tonnes and Percentage) 

(Total Fly Ash Generated=56.65MT; Total Fly Ash Utilized= 30.41 MT) 

AGRICULTURE, 1.31, 

4% 

OTHERS, 3.30, 11% 

CEMENT, 14.34, 47% 

MINEFILLING 

1.95, 7% 

RECLAIMATION, 3.23, 

11% 

ROADS & 

EMBANKMENTS, 

4.30, 14% 

BRICKS, 1.94, 6% 

CEMENT BRICKS ROADS &EMBANKMENTS 

RECLAIMATION MINEFILLING AGRICULTURE 

OTHERS 

Graph -II 

PROGRESSIVE ASH GENERATION &UTILIZATION OF COAL/ LIGNITE 

BASED THERMAL POWER STATIONS (1996-97 to 2007-08) 

140 

120 

NOs. OF TPS 

CAPACITY (MWX1000) 

ASH GENERATION (MTPA) 

ASH UTILIZATION (MTPA) 

%AGE ASH UTILIZATION 

UNUTILIZED FLY ASH (MTPA) 

100 

80 

60 

40 

20 

0 

1996- 1997- 1998- 1999- 2000- 2001- 2002- 2003- 2004- 2005- 2006- 2007- 

97 98 99 00 01 02 03 04 05 06 07 08 

No.of TPStns. covered 68 76 75 76 77 74 76 83 84 85 85 85 

Instd.cap. covered 46.5 53.3 53.4 56.5 55 54.6 57.3 62 63.4 65.5 67.6 70.1 

MWx1000 

Flyash production MTPA 68.9 78.1 79 74 86.3 82.8 91.7 96.3 98.6 99 108 116.9 

Flyash Utilization MTPA 6.64 8.43 9.6 10.9 13.5 15.6 20.8 28.2 37.5 45.3 55.1 62 

%age Utilization 9.634 10.8 12.2 14.7 15.65 18.85 22.68 29.3 38.1 45.79 50.92 53.00 

Unutilized Flyash (MTPA) 62.2 69.6 69.4 63.1 72.8 67.2 70.9 68.1 61.1 53.7 53.1 55 


87


Chart -III 

Mode of Fly Ash Utilization for the Year 2007-08 

(Mode,Quantity utilized in mt and Percentage) 

Total Fly Ash Generated=116.94MT 

Total Fly Ash Utilized=61.93MT 

AGRICULTURE, 

2.24, 4% 

MINEFILLING, 4.07, 

7% 

RECLAIMATION, 

8.33, 13% 

OTHERS, 3.12, 5% 

CEMENT, 28.76, 

46% 

ROADS & 

EMBANKMENTS, 

11.97, 19% 

BRICKS, 3.49, 6% 

CEMENT 

ROADS &EMBANKMENTS 

MINEFILLING 

BRICKS 

RECLAIMATION 

AGRICULTURE 

OTHERS 

Simhadri Super Thermal Power Station 1000 MW (2×500 MW) (A.P.) 

***** 



CHAPTER – 7 

DISTRIBUTION AND RURAL ELECTRIFICATION 

7.1 Accelerated Power Development and 

Reforms Programme (APDRP) 

CEA had been appointed as the Advisercum-Consultant 

for the State of J&K for APDRP 

schemes during 10 th Plan. APDRP schemes, 

which are estimated to cost Rs.1100.13 crores, 

have been sanctioned in respect of Sub- 

Transmission & Distribution (ST&D) schemes 

of J&K which are under progress and are 

expected to be completed in the 11 th Plan. 

The schemes covered creation of new 66/11 

kV and 33/11 kV sub-stations, augmentation of 

33/11 kV substations, addition and augmentation 

of distribution transformers, reconductoring and 

addition of new 33 kV, 11 kV and LT lines, metering 

and meter testing facilities, communication 

facilities, consumer indexing and distribution 

automation etc. 

Sl. No. Scheme for the Circle /town Estimated cost (Rs. Crores) 

1. Jammu Circle I 174.07 

2. Jammu Circle II 145.55 

3 Jammu Circle III (Batote Circle) 95.62 

4 Srinagar Circle I & II 227.03 

5 Bijbehara (Anantanag & Phulwama), South Circle 217.78 

6 Sopore (Baramula & Kupwara), North Circle 240.08 

Total 1100.13 

An amount of Rs.705.53 crores has been 

released and Rs.722.00 crores has been utilized. 

CEA is regularly monitoring the 

implementation of APDRP schemes in various 

Circles of J&K and there has been considerable 

reduction in DT failure rate, AT&C loss and 

improvement in reliability of Power Supply 

where metering of consumer installation have 

been completed and new sub-station have been 

commissioned. The schemes are in the process 

of short closer. 

7.2 Status of Metering 

CEA made a presentation on metering issues 

among Working Group constituted on metering 

issues by CERC at Almora. The presentation 

included various practices being followed in 

respect of installation and operation of meters. 

7.3 National Awards to Power Utilities 

for Meritorious Performance during 

2007-08 

(a) Distribution Companies 

The performance of Power Utilities was 

assessed on the basis of a number of distribution 

indices, viz. AT&C losses, Metering (11 kV, 

consumers and Distribution Transformers), Reliability 

of Power Supply and Financial Turnaround. The 

National Awards for meritorious performance for the 

year 2007-08 were given to APEPDCL (AP), BEST 

(Maharashtra) and NDPL, Delhi by H.E. President 

of India in New Delhi on February 17, 2009. 

(b) Rural Distribution Franchisee (RDF) 

The performance of RDF was assessed 

on the basis of a number of distribution 


89


indices, viz. Type of activities, Metered service 

connections, and Revenue Management. The 

National Awards for meritorious performance 

for the year 2007-08 were given to Mandal 

Mahila Samakhya, Kurupam, APEPDCL (AP), 

Amit Kumar, NPCL, UP and Mandal Mahila 

Samakhya, Paderu, APEPDCL (AP) by H.E. 

President of India in New Delhi on February 

17, 2009. 

7.4 Guidelines for Specifications for 

Transformers 

Guidelines for Specification of Energy 

Efficient outdoor type three phase and single 

phase Distribution transformer have been issued. 

CEA has recommended utilization of distribution 

transformers conforming to minimum three star 

rating of BEE upto 200 kVA and suggested losses 

for other rating of transformers as well based on 

higher efficiency. 

7.5 Energy Meter Related Issues 

‣ A Committee was constituted by MoP under 

the chairmanship of Chief Engineer (DP&D) 

to examine the requirement of modifying 

the tolerance limit of accuracy of electricity 

meters in light of use of electronic meters 

and to recommend accuracy and tolerance 

limits. The Committee has long time back 

submitted its report to MoP. 

‣ A High Level Committee was formed under 

the chairmanship of Member (GO&D), CEA 

to examine the adoption of open standard 

protocol for new meters to be procured. As 

a follow up action to the recommendation of 

above High Level Committee on Protocol 

Implementation, a Committee under the 

chairmanship of DG, CPRI comprising of 

Chief Engineer (DP&D), CEA, officers from 

utilities, manufacturers, was constituted to 

identify the object codes for various electrical 

and abstract parameters and to recommend 

implementation strategy. The report has been 

finalized and under RAPDRP the same is 

being adopted. Companion Standard is under 

finalization by BIS. 

7.6 Earthing of LV System 

CEA made a presentation to Gujarat 

Electricity Regulatory Commission (GERC) on 

issues related with the Earthing of LV system and 

resolved the issues between GERC and Consumer 

Education Research Society. CEA rendered 

technical advise to GERC regarding the type of 

Earthing for LV systems. 

7.7 Distribution System Improvement in 

Union Territories 

CEA renders technical assistance to 

the UTs viz Andaman & Nicobar Islands, 

Lakshadweep Islands, Dadra & Nagar Haveli, 

Daman & Diu, Puducherry, Chandigarh & Delhi 

including NDMC in project/ DPR formulation, 

technical clearance of Generation, Transmission 

& Distribution Schemes of UTs, preparation of 

specification for procurement of equipment, 

vetting of NITs/ acceptance of tenders, advise 

to UT Administration on specific technical, 

organizational and staff matters as and when 

referred to etc. Technical advise to Ministry of 

Development of North East Region (DONER) 

and National Capital Region Planning Board 

(NCRPB) is also rendered as and when 

requested. 

7.7.1 Andaman & Nicobar (A&N) Islands 

The DPR for “Restoration/Revival of the 

Power Sector in the various islands of UT of A&N 

Islands affected by Earthquake and Tsunami on 

26.12.04” was cleared by EFC/ CCEA at an 



estimated cost of Rs 198.82 Crores and is presently 

under various stages of implementation. 

The Revised Cost Estimates (RCE) of the 

above DPR, submitted by UT Administration at an 

estimated cost of Rs. 297.53 Crores was examined 

and comments were sent to MoP. 

Draft PIB Memo for RCE for DPR 

for Restoration /Revival of damaged power 

supply infrastructure in various Islands / Areas 

in Andaman & Nicobar Island affected by 

Earthquake & Tsunami on 26.12.2004 was 

vetted and comments sent to MoP. 

Examination of the schemes for augmentation 

of DG capacity & associated T&D system at 

Havelock, Neil, Long & Teressa Islands of UT 

of A&N Islands. 

7.7.2 Lakshadweep 

The following schemes were accorded 

technical clearance- 

Scheme for augmentation of distribution 

system at Agatti Island during 11 th Plan 

period in UT of Lakshadweep 


system at Kelpani Island during 11 th Plan 



system at Chetlet Island during 11 th Plan 



system at Kiltan Island during 11 th Plan 



system at Kadmat Island during 11 th Plan 


7.7.3 Dadra & Nagar Haveli (D&NH) 



Integrated solution for Electrical network 

modeling & distribution analysis 

software for Electricity Deptt. of UT of 

D&NH. 

Scheme for establishment of new 66/11 

kV, 2x15 MVA S/S at Waghdhara in UT 

of D&NH. 

Scheme for augmentation of 220/66 kV 

Kharadpada S/S from 3x100 MVA to 

4x100 MVA in UT of D&NH. 


Silly S/S from 30 MVA to 50 MVA in 

UT of D&NH. 

Examination of the technical bids 

for procurement of Comprehensive 

Power Distribution Network planning 

& management Software for UT of 

D&NH. 

7.7.4 Daman & Diu 



Scheme for Integrated solution for 

Electrical network modeling & 

distribution analysis software for 

Electricity Deptt of UT of Daman & 

Diu 

Revised Cost Estimates (RCE) for the 

scheme for establishment of 66/11 kV, 

2x10 MVA Ringanwada S/S at UT of 

Daman 


Verkund S/S from 32 MVA to 52 MVA 

at in UT of Daman 

Scheme for Normal development works 

during 2008-09 in UT of Daman & 

Diu 


91


The tenders for Annual Maintenance 

Contract (AMC) for Operation & 

Maintenance(O&M) of 220/66/11 kV 

S/S at Magarwada, 66/11 kV Ringanwada 

& Verkund S/S and associated 66 kV 

lines in UT of Daman was technically 

examined & comments were sent to UT 

Administration. 

7.7.5 Delhi/ NDMC / NCRPB 

Rendering assistance to National Capital 

Region Planning Board (NCRPB) for preparation 

of Functional Plan for Power 2021 for National 

Capital Region. 

5 ST&D schemes of Manipur State under 

NLCPR were technically examined and comments 

sent to Ministry of Development of North Eastern 

States ( DONER). 

7.7.6 Other works 

Conduction of Mock test exercise at CPWD 

11 KV Parliament House S/S to test the reliability 

of power supply to Parliament House before 

commencement of each Parliament Session. 

Examination of the R&D projects on 

Distribution Sector during 11 th Plan period and 

preparation of material for Standing Committee 

meeting on R&D under the Chairmanship of 

Chairman CEA. 

7.8 Rural Electrification 

7.8.1 Status of Rural Electrification in the 

Country 

During 2008-09 (Upto Feb., 2009), 487 

inhabited villages have been electrified and 230654 

pump sets have been energized. Cumulatively, 

488926 inhabited villages constituting 82.3% 

have been electrified out of a total of 593732 

inhabited villages and 15905327 pump sets have 

been energized in the country. 

It is observed that: 

● 

● 

● 

7 States namely Andhra Pradesh, Delhi, Goa, 

Haryana, Kerala, Punjab and Tamil Nadu and 

all UTs except Andaman & Nicobar islands 

have achieved 100% village electrification. 

12 States namely Gujarat, Himachal 

Pradesh, J&K, Karnataka, Madhya Pradesh, 

Chattisgarh, Maharashtra, Manipur, Sikkim, 

Uttar Pradesh, Uttaranchal & West Bengal 

have achieved more than the national average 

of village electrification (82.3%). 

10 States namely Arunachal Pradesh, Assam, 

Bihar, Jharkhand, Meghalya, Mizoram, 

Nagaland, Orissa , Rajasthan & Tripura are 

lagging behind the national average of village 

electrification. 

The charts at the end of this chapter show 

the Plan-wise and State-wise progress of village 

electrification and pump sets energisation as on 

28.02.2009. 

7.8.2 Continuation of Rajiv Gandhi 

Grameen Vidyutikaran Yojna in 11 th 

Plan – Scheme of Rural Electricity 

Infrastructure and Household 

Electrification 

Central Govt. launched a scheme “Rajiv 

Gandhi Grameen Vidyutikaran Yojna of Rural 

Electricity Infrastructure and Household 

Electrification” on 4 th April,2005 for the attainment 

of the National Common Minimum Programme 

(NCMP) goal for providing access to electricity 

to all households in the country in five years. 

The scheme aimed at electrification of 125,000 

un-electrified villages and un-electrified hamlets 

and electrification of 7.8 crore households. The 

estimated cost of the scheme (including 11 th Plan) 

was Rs.16000 crores approximately and Rs.5000 



crores were earmarked for capital subsidy in 

phase- I during the 10 th Plan Period. 

Under the scheme, projects were financed 

with 90% capital subsidy by the Central 

Government for provision of Rural Electricity 

Distribution Backbone (REDB), Creation of 

Village Electrification Infrastructure (VEI) and 

Decentralised Distributed Generation (DDG). 

There is a provision of subsidy of Rs. 540 crores 

for DDG under the scheme. Guidelines for village 

electrification through Decentralized Distributed 

Generation (DDG) under RGGVY in the 11 th 

Plan has been approved and circulated vide OM 

No.44/1/2007-RE dated 12 th January, 2009. 

Continuation of the scheme during 11 th 

Plan for providing excess to electricity to the 

all households by 2009 has been approved by 

Government of India with a capital subsidy of 

Rs. 28000 crores. 

CEA informed the Monitoring Committee, 

MoP, regarding the implementation of RGGVY; 

59882 number of villages and 63.47 lakhs 

households including 53.78 lakhs BPL households 

have been electrified under the scheme upto 

31.03.2009. Rs.13556.08 crores has been released 

upto 31.03.2009. The projects under the scheme 

will be subjected to Three Tier Quality Control 

Mechanism. 

7.8.3 Other works 

‣ Prepared comments / material regarding 

rural electrification on the points raised 

in summary records of discussions of 

the various meetings of the committees 

such as Standing Committee on Energy, 

Consultative Committee on Power and 

National Conference of Chief Secretaries 

etc. 

‣ Furnished draft material for replying to 

Parliament Questions, VIP references, 

Annual Report of MoP & CEA. 

‣ Notes were prepared on rural electrification 

in North Eastern Region in respect of PMO 

references. 

‣ Comments sent in respect of rural 

electrification on the recommendations 

contained in thirty fourth report of the 

Committee on Public Undertaking (2008- 

09) on physical & financial performance of 

Power Generating PSUs. 

‣ Clarifications / comments sent on the minutes 

of the meeting of the Consultative Committee 

of Member of Parliament for the Ministry of 

Power held on 15 th December, 2008 in New 

Delhi. 

‣ Comments sent on the recommendations 

contained in the 13 th Report of the Standing 

Committee on Energy on “Role of CERC 

and SERCs in protection of interests of 

Consumers” pertaining to the Ministry of 

Power. 

‣ Information furnished in respect of rural 

electrification for the questionnaire on 

National Electricity Policy,National Tariff 

Policy & Rural Electrification Policy. 


electrification for post evidence list of points 

for written replies from Ministry of Power for 

Committee on Public Undertaking(COPU) in 

connection with examination of physical and 

financial performance of Power Generating 

PSUs. 


electrification for local visit of Committee 

on Subordinate Legislation, Rajya Sabha on 

24 th January,2009. 


93


Villages electrified statewise(as on 28th February,2009) 

100000 

90000 

86450 

80000 

70000 

Villages Electrified 

60000 

50000 

40000 

30000 

20000 

10000 

0 

Uttar Pradesh 

50226 

Madhya Pradesh 

36462 

West Bengal 

36296 

Maharashtra 

27126 

Karnataka 

27373 

Rajasthan 

26613 

Andhra Pradesh 

26535 

Orissa 

20620 

Bihar 

19741 

Assam 

18877 

Chattisgarh 

18014 

Gujarat 

17183 

Himanchal Pradesh 

15400 

Tamil Nadu 

Uttaranchal 

15213 

Punjab 12278 

9119 

Jharkhand 

6764 

Haryana 

6304 

Jammu & Kashmir 

3428 

Meghalaya 

2195 

Arunachal Pradesh 

1984 

Manipur 

1364 

Kerela 

823 

Nagaland 

570 

Mizoram 

491 

Tripura 

425 

Sikkim 

347 

Goa 

158 

Delhi 

547 

UTs 

State 

NOS. OF PUMPSETS ENERGISED 

16000000 

14000000 

12000000 

10000000 

8000000 

6000000 

4000000 

2000000 

0 

NO. OF PUMPSETS ENERGISED PLANWISE (CUMULATIVE) 

21008 

5605 8 

1989 04 

512 756 

108 8804 

242613 3 

329990 1 

39 65828 

5708563 

8350790 

9 391108 

11565342 

11849406 

12216650 

12514244 

1 2825304 

13141378 

13792473 

14115 441 

14446461 

1484380 4 

15368577 

15674673 

1 5905327 

1951 1956 1961 1966 1969 1974 1978 1980 1985 1990 1992 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008Feb.,09 

PLAN PERIODS(ENDING MARCH) 

******* 



CHAPTER – 8 

DESIGN & ENGINEERING SERVICES 

8.1 Design & Engineering of Hydro 

Electric Projects 

Central Electricity Authority renders design 

& engineering services for detailed engineering 

to Hydro Power Projects under execution in the 

Central/State Sectors and neighbouring countries. 

Design & Engineering includes complete design, 

techno-economic analysis, and preparation 

of specifications, tender evaluation, selection 

and sizing of equipments, detailed layout and 

schematic drawings for hydro turbine, generator, 

transformer, switchyard equipment and other 

auxiliaries. 

The legacy of CEA in rendering the design 

and engineering of Hydro Electric Projects is for 

a period of 48 years since 1960. Seventy five (75) 

hydro electric projects in India and neighbouring 

countries having aggregate installed capacity of over 

15757 MW (see Annexure-8A) were completely 

designed and engineered by this organisation 

during this period are in successful commercial 

operation. The design consultancy of hydro electric 

projects include projects with conventional hydro 

generating units, bulb/tubular type units, pumped 

storage schemes and underground power stations 

with unit capacity from few kW to 250 MW. CEA 

is fully equipped to provide state of the art design 

and engineering services for hydro power projects 

of any type and capacity. 

8.2 Preparation of DPRs of new HE 

Projects 

The Chapters for Electro-Mechanical 

Equipment alongwith related drawings and bill 

of material for DPRs of Nyukcharangchu HE 

Project (3x55 MW), Arunachal Pradesh, Ken 

Betwa Link Canal H. E. Project (2x20 MW + 3x6 

MW) Madhya Pradesh, Seli HE Project (4x80 

MW), Himachal Pradesh and Raoli H. E. Project 

(4x105MW), Himachal Pradesh were prepared 

under consultancy assignment. 

8.3 Scrutiny of proposals for Foreign 

Assistance/Bilateral Co-operation for 

HE Projects. 

Various proposals regarding foreign 

assistance / bi-lateral co-operation pertaining to 

HE Projects as received from Ministry of Power 

were examined and commented upon. 

8.4 Scrutiny of Bill of Quantity (BoQ) of 

Small HE Schemes Certification as 

Capital Goods 

Bill of Quantity (BoQ) of 8 nos. of small/ 

mini HE schemes viz. Manjanadaka (2x5 MW), 

Dadupur (4x1.5 MW), Kadamane (4x7.5 MW), 

Varahi Tail Race (2x7.5 MW), Dandela (3x4.35 

MW), Birahi Ganga (2x2.4 MW), Somanamardi 

(1x6 MW), Somavathi (2x3 MW) comprising of 

electromechanical. equipment for the generating 

units, associated auxiliaries, transmission lines 

etc. received for the purpose of certification as 

capital goods were examined and commented 

upon. 

8.5 Assessment of Requirement of 

Electrical Equipment and Steel for 

12 th & 13 th Plan Period 

An assessment regarding the requirement 

for electrical equipment and steel for various 

hydro projects to be taken up during 12 th and 13 th 

plan was made. 


95


8.6 Other Miscellaneous Works 

The following proposals were received for 

examination and comments: 

(i) Draft for Manual for prevention against 

flooding of Hydro Power Stations 

received from CBIP. 

(ii) 2 Nos. documents pertaining to small 

Hydro Power Plant received from 

CBIP. 

(iii) Proposal for Upgradation of 400kV 

XLPE Cable Termination of Tala HEP 

received from THPA, Bhutan. 

(iv) Draft O&M manuals of GIS, Potheadyard 

equipment and Computerised Control 

System (Vol. 3 & 4) for Tala H.E 

Project. 

(v) Draft standards received from BIS 

regarding methods of measurements of 

works in river valley projects (Dams 

and Appurtenant) part 19 of electromechanical 

works WRD 23. 

8.7 Programme and Achievement during 

2008-09 

During 2008-09, CEA continued consultancy 

services for design and engineering of electrical 

and mechanical works of ten (10) hydro electric 

projects. Out of these, eight (8) projects are in 

India and two (2) are in neighbouring countries 

with aggregate installed capacity of about 

3363MW including large hydro power projects 

such as Loharinag Pala (4x150 MW), Tapovan 

Vishnugad (4x130 MW) and Punatsangchu St.I 

(6x200 MW), Bhutan. The Hydro Power Projects 

for which design & engineering services were 

rendered by CEA during 2008-09 are shown 

below:- 

HYDRO POWER STATIONS FOR WHICH DESIGN & ENGINEERING SERVICES 

ARE BEING RENDERED BY CEA 

S.No Project State/Executing Agency Capacity (MW) 

Northern Region 

1. Koteshwar Uttarakhand/THDC 4x100 

2. Loharinag Pala Uttarakhand /NTPC 4x150 

3. Tapovan Vishnugad Uttarakhand /NTPC 4x130 

4. Rampur Himachal Pradesh/ SJVNL 6x68.67 

North Eastern Region 

5. Myntdu Leshka Meghalaya/MeSEB 2x42 

6. Myntdu Leshka(Extn.) Meghalaya/MeSEB 1x42 

7. Ganol Meghalaya/MeSEB 3x7.5 

8. New Umtru Meghalaya/MeSEB 2x20 

Neighbouring Countries 

9. Punatsangchu St.I Bhutan 6x200 

10. Salma Afghanistan/WAPCOS 3x14 

Total 3363 

Some of the major works completed during the 

year under consultancy services are detailed in 

the following para. 

10 (Ten) technical bids for auxiliary 

equipment were evaluated and about 6,000 sheets 

of manufacturer’s drawings were examined for 

Koteshwar H.E.Project (4x100 MW), Myntdu 



H.E.Project (2x42 +1x42 MW), Loharinag Pala 

(4x150 MW), Tapovan Vishnugad H.E.Project 

(4x130 MW) & Salma H.E.Projects, (3x14 MW). 

Tenders for Generator Transformers and 400 kV 

XLPE cables of Loharinag Pala H.E.Project were 

evaluated and also participated in the pre and post 

bid meetings. Design memos for 11 (eleven) nos. of 

E&M equipments for Loharinag Pala H.E.Project 

were examined. Civil construction drawings (90 

nos.) for Loharinag Pala H.E.Project (4x150 MW), 

Koteshwar H.E.Project (4x100 MW) and Myntdu 

H.E.Project (2x42 MW) were examined. During the 

year, layout drawings of Power house, Switchyard 

etc. were also finalized for the Myntdu H.E.Project 

(2x42 +1x42 MW), Loharinag Pala H.E.Project 

(4x150 MW), Tapovan Vishnugad H.E.Project 

(4x130 MW) & Salma H.E. Project, (3x14 MW). 

Tender document and Tender evaluation report 

for Rampur H. E. Project (6x68.67 MW) were 

vetted. 

Technical specification for Punatsangchu (Stage-I) 

H. E. project (6x200 MW), Bhutan were under 

finalization and 20 specification drawings were 

prepared. 

The pre-qualification bids of Ganol H.E. Project 

(3x7.5 MW) and technical bids for New Umtru 

H.E. Project (2x20 MW) were also examined. 

8.8 Design and Engineering of Thermal 

Projects 

The following design & engineering assignments 

as a part of consultancy work were carried out: 

(a) Review consultancy for Yamunanagar 

Thermal Power Project (2x300 MW) 

(b) Review consultancy for Hisar Thermal Power 

Project (2x600 MW) 

(c) Review consultancy for Raghunathpur TPP 

(2x600 MW) 

(d) R O plant for Karaikal combined cycle gas 

power plant 

(e) Ash handling system of unit 4 of Kutch 

Lignite TPS 

8.9 Design & Consultancy Assignments 

(Civil aspects) for Thermal/ Hydro/ 

Power Transmission Projects 

CEA is carrying out Techno-economic 

Appraisal of Hydro-electric Power Projects and 

rendering consultancy services for detailed design 

& engineering to the thermal power projects and 

power transmission schemes. The civil aspects of 

cost estimates for stage-I and stage-II activities of 

hydro power projects under three-stage clearance 

are also being examined. 

CEA carried out detailed design & 

engineering for 8 thermal / hydro and power 

system projects in respect of civil engineering 

works involving preparation of technical 

specification & tender drawings, bill of quantities, 

tender evaluation, preparation of detailed design 

and construction drawings for civil structures 

including scrutiny of designs and drawings 

of civil works received from turnkey vendors 

/ manufacturers / contractors. CEA is also 

providing necessary assistance for civil and 

structural engineering works pertaining to hydro 

power projects being referred to CEA. The 

works carried out during the year as consultancy 

assignments are shown in Annexure-8 B. 

8.9.1 Consultancy and Technical support 

(a) The technical specifications for Remote 

Terminal Unit (RTU) and Power Line Carrier 

Communication (PLCC) system for existing 

and new 132kV and 220kV power line 

network in Kashmir region was prepared by 

CEA and forwarded to Power Development 

Department (PDD), Government of J&K and 

NIT for the same has been issued by PDD. For 

Jammu region, the technical specifications for 

RTU and PLCC for existing and new 132kV 


97


and 220kV power network are complete and 

the same are being forwarded to PDD, J&K 

for further necessary action. 

(b) Narmada Control Authority (NCA) has 

installed an RTU at River Bed Power House 

(RBPH) at Narmada Complex in Kevadia, 

Gujarat to enable transmission of data to 

Western Regional Load Despatch Centre 

(WRLDC) as an interim arrangement. 

Technical support for the same has been 

provided by CEA. 

(c) Technical specifications were prepared 

by CEA and forwarded to Meghalaya 

State Electricity Board (MeSEB) and NIT 

for the same has been issued for Telecommunication 

and Supervisory Control 

and Data Acquisition (SCADA) system. 

The bid evaluation is under progress. CEA 

is providing technical assistance to Leshka 

Hydro Electric Project Authority, MeSEB for 

carrying out technical bid evaluation. 

(d) Technical support and input has been provided 

to M/s WAPCOS for PLCC equipment and 

48V DC power supply system, EPABX 

system and associated accessories for Salma 

Dam HEP in Afghanistan. 

(e) CEA participated in the meetings organized by 

BIS, CIGRE, etc. A meeting of Power System 

Control and Associated Communications- 

Sectional Committee- LITD 10 in joint 

session with SCADA Working Group for 

Power Sector was organized by BIS on 13 th 

March 2009 at New Delhi to discuss Indian 

Standard on SCADA. 

Karcham Wangtoo Project Surge Shaft—Widening To Full Size From Top 

***** 



CHAPTER – 9 

ECONOMIC AND COMMERCIAL - aspects of power industry 

The Electricity Act, 2003 was notified in 

June, 2003. The Act replaces the three earlier Acts, 

namely, the Indian Electricity Act 1910, Electricity 

(Supply) Act, 1948 and the Electricity Regulatory 

Commission Act, 1998. As per the 2003 Act, 

CEA has inter-alia been entrusted with duties 

and functions relating to collection/recording 

of data/information relating to generation, 

transmission, distribution, trading and utilization 

of electricity and to carry out studies relating to 

cost, efficiency, competition etc. to evaluate the 

financial performance of the power sector. 

9.1 Performance of State Electricity 

Boards/ State Power Utilities 

9.1.1 Average realization vis-a` vis Average 

Cost of Supply 

The average cost of supply of electricity 

was 246 paise/unit during 2001-02. It decreased 

to 238 paise/unit during 2002-03. Thereafter it 

gradually increased to 276 paise/unit during 

2006-07.The average realisation from sale of 

power has gradually increased from 181 paise 

per unit during 2001-02 to 227 paise per unit 

during 2006-07. The table below gives the 

average cost of supply and average realization 

covering all sectors in the country on the basis 

of the data made available by various SEBs/ 

Utilities:- 

Average Cost of Supply and Average Realization of Electricity from All Sectors (in paise/unit) 

Year Average Cost of Supply Average Realisation Gap 

2001-02 246.00 181.00 65.00 

2002-03 238.00 195.00 43.00 

2003-04 239.00 203.00 36.00 

2004-05 254.00 209.00 45.00 

2005-06 258.00 221.00 37.00 

2006-07 276.00 227.00 49.00 

Source: 1. PFC Reports on the performance of the State Power Utilities. 

9.1.2 Commercial Losses 

Various power utilities in the country 

suffered losses of Rs.21192 crores (2002- 

03), Rs.19107 crores (2003-04), Rs.23995 

crores (2004-05), Rs.20131 crores (2005-06) 

and Rs.27446 crores (2006-07) respectively 

without subsidy. Year-wise commercial losses 

of power utilities for the period 1991- 

92 to 2006-07 are indicated in the table 

below:- 

Year-wise Commercial Losses of Power Utilities 

Year Losses (Rs. In crores) 

1991-92 3000 

1992-93 4560 

1993-94 5060 

1994-95 6125 

1995-96 8770 

1996-97 11305 

1997-98 13963 

1998-99 20860 

1999-00 26353 

2000-01 25259 


99


2001-02* 29331 

2002-03* 21245 

2003-04* 19237 

2004-05* 23996 

2005-06* 20131 

2006-07* 27446 

Source: i) Data upto 2000-01 is based on Annual 

Report on the Working of SEBs/Ellectricity Deptts. 

Published by Planning Commission (2002) 

ii) *PFC Reports on the performance of the State 

Power Utilities. 

9.1.3 Settlement of Dues 

The gap between average revenue 

realization and average cost of supply constantly 

increased. All this caused erosion in the volume 

of internal resources generation by the SEBs 

and led them to virtual bankruptcy. The level 

of commercial losses of the SEBs/ utilities 

depended inter-alia on the unaccounted energy 

losses, effective subsidies incurred towards 

sales to agriculture and domestic sectors, efforts 

to neutralize them through cross subsidization 

and the level of subventions provided by the 

State Governments. Gross subsidy on energy 

sales had been increasing over the years because 

of the policy of some of the states to provide 

electricity at subsidized rates to agriculture and 

domestic consumers. 

Consequently SEBs were unable to make 

full payments to CPSUs for purchase of power 

and coal resulting in accumulation of huge 

outstanding amount to be paid by SEBs. This 

adversely affected the growth and performance 

of Central Power Sector Utilities (CPSUs). This 

payment deficit continues to rise and threaten 

the viability of the Central Power Utilities. Poor 

credit worthiness of SEBs has also effectively 

blocked investments by the private sector despite 

the enabling and encouraging framework laid 

down by the Centre. Even in the post reform 

period, managerial and financial inefficiency 

in the state sector utilities adversely affected 

capacity addition and system improvement 

programmes. 

In pursuance of the reforms process, the 

expert group formed by the Govt. of India under 

the Chairmanship of Member( Energy), Planning 

Commission recommended a scheme for one 

time settlement of dues payable by the SEBs to 

CPSUs and Railways. This one time settlement 

scheme of dues (launched in 11 th May, 2001) 

owed by SEBs/Utilities to CPSUs, was aimed at 

making loss making power utilities bankable. In 

terms of the Scheme, 60% of interest/surcharge 

on the delayed payments/dues as on 30.9.2001was 

waived and the rest of the dues were securitized 

through tax-free bonds issued by respective State 

Governments. 

Considerable progress has been made since 

then in the settlement of dues payable by SEBs to 

CPSUs and the Railways. All State Governments 

signed the tripartite agreement envisaged under the 

scheme, which was between the State Government, 

Reserve Bank of India and the Government of India. 

Out of these, 27States have issued bonds amounting 

to Rs. 31581 crore. Goa had no outstanding dues. 

The Government of the National Capital Territory of 

Delhi securitized its outstanding dues by converting 

the dues into long-term advances of Rs. 3,376 crore 

payable to the CPSUs concerned separately under 

bi-partite Agreements, as they do not have the power 

to issue bonds. 

9.1.4 Trend in Outstanding Dues to CPSUs 

by SEBs/Utilities 

CEA has been monitoring the status of the 

outstanding dues payable by SEBs to CPSUs. The 

total dues outstanding to various CPSUs for the 

period 2002-03 to 2008-09 are given in the table 

below:- 



Year 

Total Outstanding Dues (Rs. Crore) 

2002-03 41490.70 

2003-04 8093.76 

2004-05 6248.15 

2005-06 2601.22 

2006-07 2937.39 

2007-08 3596.11 

2008-09 4286.58 

As reported by CPSUs (upto 31 st march of the year) 

A statement indicating the status of outstanding 

dues as per the information received from CPSUs 

up to 31-03-09 is given in Annexure-9A. 

9.2 Tariff and average rates of electricity 

supply and electricity duty 

In fulfillment of its obligation under Section 

73(i) & (j) of the Electricity Act, 2003, CEA 

brings out a publication titled “Electricity Tariff & 

Duty and Average Rates of Electricity Supply in 

India”. The latest edition (March, 2008) contains 

information on tariffs applicable in various States/ 

Utilities as effective on 31st July, 2007. Average 

rates of electricity supply presented in this edition 

have been worked on the basis of the tariff 

orders issued by the State Electricity Regulatory 

Commissions and tariff notifications issued by the 

concerned SEBs/ Power Departments/ Utilities. 

Further, the publication incorporates a 

comparative study of estimated average rates of 

electricity in various states of the country. Though, 

it is somewhat difficult to compare the tariffs 

applicable in the various States, as the parameters 

considered by the State Electricity Boards/State 

Electricity Regulatory Commissions for fixing 

consumer tariff are not identical, an attempt has 

been made to workout average rates for various 

categories of consumers for the purpose of a 

broad comparison. The methodology followed 

involves assumption of certain sanctioned load 

(kW) and monthly electricity consumption (kWh) 

level for each category of consumers separately. 

Considering the rates of sale of electricity for 

various slabs as notified by the supplier, the 

average per unit rate have been worked out. 

The electricity duty/ taxes applicable are added 

to these rates to arrive at the estimated average 

per unit cost payable by different categories of 

consumers. 

A statement indicating estimated average 

category-wise rates of electricity for various 

utilities in the country updated up to 31.03.2009 

is given at Annexure-9B. 

9.3 Certification by CEA for deemed 

export benefits under Export-Import 

Policy 

Proposals regarding essentiality certification 

in respect of supplies to the projects made by the 

domestic supplier as “Capital Goods” for the 

following power projects were examined during 

the year: - 

(a) Kadamane Mini Hydel Scheme-2 (2x75 

MW), Karnataka of M/S Nagarjuna Hydro 

Energy Pvt. Ltd. 

(b) Manjadka Mini Hydel Scheme (2x5MW), 

Karnataka of Bhoruka Power Corporation 

Ltd. 

(c) Birahi Ganga Hydro Power Project 

(2x2.4MW), Uttaranchal of M/s Birahi 

Ganga Hydro Power Project Ltd., New 

Delhi 

(d) Somavathi Mini Hydel Power Project 

(2x3MW), Karnataka,of M/S SRM Power 

Private Ltd.,Bangalore. 

(e) Varahi tail race Mini Hydel Scheme-II 

(2x7.5MW), Karnataka, of Sandur Power 

Company Ltd. 

(f) Group Captive Coal Based Thermal Power 

Plant(2x63MW), Keelavela-yudhapuram, 


101


Tuticorin, of Indo-Barath Powergencom Ltd., 

Chennai. 

(g) Toss Mini Hydel Project (2x2.5MW), 

Himachal Pradesh of Sai Engineeering 

Foundation, New Shimla. 

(h) Dadupur Small Hydel Project (4x1.5MW), 

Haryana of Bhoruka Power Corporation Ltd. 

(i) Dandela Mini Hydel Scheme- (13 MW), 

Karnataka of Sagar Power (Dandela) Pvt. Ltd. 

Essentiality certification in respect of 

Capital Goods for availing “Deemed Export” 

benefits by the indigenous suppliers under 

the EXIM Policy was done for the projects at 

Serial No. (a) and (b) above. 

However, as per Hand Book of Procedures 

(HBP) Volume-I of Foreign Trade Policy (2004- 

2009), Central Electricity Authority’s certification 

is no longer required for the purpose of obtaining 

the deemed export benefits. In view of this, all the 

project authorities whose cases were pending in 

CEA have been informed accordingly. 

9.4 References on techno-financial matters 

in power sector 

The following references on issues 

concerning technical/financial matters of power 

sector were received from MoP/other Central Govt. 

Ministries/ Trade and Industry Associations during 

the year and CEA’s comments/recommendations, 

were sent to MoP/ concerned departments. 

(i) Request for issuance of Comfort Letter by 

Government of India, Ministry of Finance 

for exemption of payment of excise duty on 

supply of equipment / material for power 

transmission projects funded by Asian 

Development Bank (ADB). 

(ii) Waiver of customs duty on Liquefied 

Natural Gas (LNG) and Naphtha used for 

power generation. 

(iii) Progress in respect of the Administrative 

Reforms Commission’s 4 th report titled 

“Ethics in Governance”. 

(iv) Request list of China and Korea for grant 

of tariff concessions under the Asia Pacific 

Trade Agreement (APTA). 

(v) Meeting to discuss the prices to be used 

for electricity sub-group for the new 

series of Wholesale Price Index (Base 

year: 2004-05). 

(vi) Request of M/s Jindal Steel & Power Ltd. for 

issue of ‘Essentiality Certificate’ for project 

import for 135 x 10 Captive Power Plants at 

Raigarh, Chhattisgarh and Angul, Orissa. 

(vii) Consideration of application/ amendment 

in EPCG licenses/Nexus Certification 

under EPCG Scheme by M/s Essar Power 

(P) Ltd. 

(viii) Identification of purely single-use 

environmental goods from the draft 

convergence list of 153 products by the 

WTO Committee on Trade & Environment 

(Special Session). 

(ix) APGCL Tender No. K7205-SPC-001-100 

MW CCPL Phase-1 at Namrup. 

(x) Chairman, Chhattisgarh SERC’s D.O.letter 

regarding potential of generation from waste 

heat of sponge iron industry. 

(xi) COS Note on Support to Domestic Capital 

Goods Industry. 

(xii) Excise duty for Mundra UMPP from M/s 

Coastal Gujarat Power Ltd(CGPL). 

(xiii) Information regarding power generating 

stations using LSHS and Naphtha as fuel. 

(xiv) Inclusion of ‘Cable’ in the list of eligible 

goods for availing Deemed Export benefits, 

while setting up of Power Projects. 



(xv) Request of M/s CGPL and M/s BHEL to 

address the inconsistency between the 

Excise Notification No. 6/2006, dated 

March 1, 2006 and Rule 6(6) of CENVAT 

Credit Rules, 2004 to get credit facility for 

UMPPs. 

(xvi) Request of M/s CGPL and M/s BHEL 

for interpretation of Notification No. 

46/2008-CX, dated August 14, 2008 

inserted as an amendment to Sl No. 91 

(entry No. 91A) in the table on General 

Exemptions and its linkage with entry No 

400 of Customs Notification No. 21/2002- 

cus, dated March 1, 2002. 

(xvii) Request of M/s CGPL for waiver and release 

of bank guarantee furnished by M/s CGPL 

for their Mundra UMPP in Gujarat. 

9.5 Data Bank for Cost of Generation of 

Power 

The process of creating a Data Bank 

regarding cost of power generation and rate of 

sale of electricity classified by type of generation 

for various Utilities/SEBs/Power Departments is 

under progress. During the year, the process of 

collection of data separately for the wind power 

generating plants /companies has also been 

started. With the creation of a large number of 

utilities in the form of distribution companies 

(DISCOMs), the work of data collection, sifting 

and compilation had increased manifold. For 

the sake of clarity and to make it possible to 

have an intra-regional comparison of the cost of 

power generation at a glance, the format has been 

changed to present the data region-wise instead 

of the alphabetical order followed in the previous 

report. Statement indicating power station-wise 

cost of generation for various Central & State 

utilities in the country for year 2007-08 is given 

at Annexure-9C. 

9.6 Progress in Bidding Process of Ultra 

Mega Power Projects (UMPPs) 

CEA was associated with the finalization 

of Request for Qualification (RFQ), Request for 

Proposal (RFP) and Power Purchase Agreement 

(PPA) for setting up of Ultra Mega Power Projects 

(UMPPs) in the country and in this regard, had 

represented in various committees. The successful 

bidders for four Ultra Mega Power Projects have 

already been selected through the tariff based 

International Competitive Bidding process, based 

on the capacity and Supercritical technology, 

specified in the RFQ & RFP documents issued by 

the shell companies and Letter of Intent has been 

issued to the successful developers. The bidders 

quoted the tariff for 25 years. Power Finance 

Corporation was the Nodal Agency for the entire 

bid process. The status of various UMPPs is as 

under: 

(i) 

Mundra UMPP (5x800 MW) in 

Gujarat 

The Letter of Intent (LOI) was awarded 

to M/s Tata Power Ltd. on 28 th December, 2006 

with a levelised tariff of Rs. 2.264 per Kwh. The 

project was handed over on 23.04.07. 

(ii) 

Sasan UMPP (6x660 MW) in Madhya 

Pradesh 

The Letter of Intent (LOI) was awarded 

to M/s Reliance Power Ltd. on 1 st August, 2007 



iii) 

Krishnapatnam UMPP (5x800 MW) 

in Andhra Pradesh 

The Letter of Intent (LOI) was awarded to 

M/s Reliance Power Ltd. on 30 th November, 2007 




103


(iv) Tilaiya UMPP in Jharkhand 

The Letter of Intent (LOI) was awarded to 

M/s Reliance Power Ltd. on 12.02.2009 with a 

levelised tariff of Rs. 1.7704 per Kwh. 

9.7 Consultancy services 

‣ Advice to UPERC 

Central Electricity Authority rendered 

advice to Uttar Pardesh Electricity Regulation 

Commission on the proposed bidding process 

(RFP) by Uttar Pardesh Power Company Limited 

(UPPCL) for 3 x 660 MW Prayagraj TPP together 

with its transmission system. 

9.7.1 Nuclear Power Tariff Fixation 

In terms of provisions of Department of 

Atomic Energy Act, 1962, CEA has examined the 

power tariff related proposals of Nuclear Power 

Corporation of India Limited in respect of - 

‣ Short recovery of Heavy Water charges from 

the beneficiaries for the period 1993- 94 to 

2003-04. 

‣ Recovery of Heavy Water inventory charges 

for period of shut down of Madras Atomic 

Power and Narora Atomic Power for carrying 

out EMCCR works. 

9.7.2 Hydro Electric Projects of Bhutan 

Studies for formulation of a model of 

power tariff for future hydro-projects of Bhutan 

were carried out by a committee set up by 


9.7.3 Development of Transmission 

Projects 

CEA engineers deliberated in the various 

committees on preparation of tariff based standard 

bidding documents for selection of Transmission 

Service Provider (TSP) on competitive bidding 

route. 

9.8 Nomination of CEA officers to Bid 

Evaluation Committees 

Officers of CEA were nominated to the Bid 

Evaluation Committee for the purpose of – 

(a) Selection of Transmission service providers 

for the following transmission system. 

(i) Transmission system enabling surplus 

power transmission from ER/NER to NR 

(ii) North Karanpura Transmission system 

(iii) Talcher –II Transmission system 

(b) Selection of bidder for Sangam TPP 

(2000MW) at Karchhana, U.P, by UPPCL. 

(c) Expert Committee constituted for evaluation 

of RFP bids for Tilaiya Ultra Mega Power 

Project in Jharkhand. 

9.9 The Electricity Act, 2003 & Follow-up 

9.9.1 Electricity (Amendment) Act, 2007 

The Electricity (Amendment) Act, 2007 

amending certain provisions of the Electricity 

Act, 2003 has been enacted on 29 th May, 2007 

and brought into force w.e.f. 15 th June, 2007. The 

main features of the Electricity (Amendment) Act, 

2007 are as follows: 

‣ Central Government jointly with State 

Government to endeavor to provide access for 

electricity to all areas including villages and 

hamlets through rural electricity infrastructure 

and electrification of households. 

‣ No license required for sale from captive 

units. 

‣ Deletion of the provision for “Elimination” of 

cross subsidies. The provision for reduction 

of cross subsidies would continue. 

‣ Definition of theft expanded to cover use of 

tampered meters and use for unauthorized 

purpose. Theft made explicitly cognizable 

offence and non-bailable. 



9.9.2 Formulation of Regulations under the 

Electricity Act, 2003 

As per Section 177 of the Electricity 

Act, 2003, the Authority has been vested with 

the powers to make regulations. Following 

regulations have been notified: 

(i) Installation & Operation of Meters – notified 

on 17.3.2006 

(ii) Procedures for Transaction of Business – 

notified on 18.8.2006. 

(iii) Technical Standards for Connectivity to the 

Grid u/s 73 (b) of the Electricity Act, 2003 – 

notified on 21.02.07. 

(iv) Furnishing of Statistics, Returns & 

Information. Notified on10.04.2007 

Following regulations are under finalization after 

following procedure of previous publication:- 

(i) Grid Standards for Operation & Maintenance 

of Transmission Lines u/s 34 of the Electricity 

Act, 2003. 

(ii) Technical Standards for Construction of 

Electrical Plants and Electric Lines u/s 73(b) 

of the Electricity Act, 2003. 

(iii) Suitable Measures relating to Safety & 

Electricity Supply u/s 53 of the Electricity 

Act, 2003. 

(iv) Safety Requirement for Construction, 

Operation & Maintenance of Electrical Plants 

& Electric lines u/s 73 (c) of the Electricity 

Act, 2003. 

The Amendment for the following regulation 

notified by the Authority is under finalization:- 

(i) Regulations on Installation & Operation of 

Meters” u/s 55(1) and 73(e) of the Electricity 

Act, 2003. 

9.10 Status of Power Sector Reforms 

9.10.1 Restructuring of State Electricity 

Boards/Electricity Departments/ 

Power Departments 

Though all the States have signed MoU/ 

MoA with MoP for unbundling/ corporatisation 

of State Electricity Boards(SEBs)/Power Deptts./ 

Electricity Departments, so far out of 21 States 

in which all matters relating to generation, 

transmission and distribution of electricity were 

managed by respective SEB, 14 States have 

reorganized their SEBs viz. Orissa, Haryana, 

Andhra Pradesh, Chhattisgarh, Karnataka, Uttar 

Pradesh, Uttrakhand, Rajasthan, Delhi, Gujarat, 

Madhya Pradesh, Assam, Maharashtra and West 

Bengal. 

Individual States have been approaching the 

Central Government from time to time seeking 

extension of time for reorganization of their State 

Electricity Boards. As per the Electricity Act, 2003, 

the period of extension of continuing the SEBs is 

to be decided mutually by the State Government 

and Central Government. While considering 

request for extension on a case by case basis, 

the Central Government takes into consideration 

the progress made in the reorganisation and then 

decides as to how much extension should be 

agreed to. The Central Government has conveyed 

its consent to the following States for extension 

of time for reorganizing the SEBs:- 

S. 

No. 

Name of State 

Extension 

accorded upto 

1. Bihar 30.06.2009 

2. Himachal Pradesh 30.06.2009 

3. Jharkhand 30.06.2009 

4. Kerala 30.06.2009 

5. Meghalaya 30.06.2009 

6. Punjab 30.06.2009 

7. Tamil Nadu 30.06.2009 


105


Besides the above, in eight States viz. 

J&K, Goa, Sikkim, Arunachal Pradesh, 

Manipur, Mizoram, Nagaland and Tripura, all 

matters relating to generation, transmission 

and distribution of electricity are managed by 

the respective Power Departments/ Energy 

Department. The Electricity Act, 2003 is silent 

about the State Power Departments. However, 

the State of Tripura (15 th State- apart from the 

14 States where SEBs have been reorgainsed) 

has created Tripura State Electricity Corporation 

Limited (TSECL) as a single Corporation to look 

after generation, transmission and distribution, 

trading, SLDC operation. In addition, there 

are six Union Territories (except Delhi) viz. 

Chandigarh, Puducherry, Lakshadweep, Andaman 

& Nicobar Island, Daman & Diu and Dadra & 

Nagar Haveli, which are having their own Power 

Departments. 

9.11 Analysis of Policy Issues 

CEA has been regularly providing 

analytical inputs on various policy issues 

referred to Central Electricity Authority by the 

Ministry of Power. The Draft Coal Regulatory 

Authority Bill was examined and crucial inputs 

regarding revision of proposed procedures were 

provided. The Ministry of Power agreed and 

directed NTPC to give its comments on the 

issues raised by Economic Cell before finalizing 

its own comment to be sent to Ministry of 

Coal. A note was sent on interpretation of the 

mega power policy to facilitate accelerated 

investment in power generation. A proposal 

for tariff based bidding of coal blocks within 

existing legal framework, so as to help in 

accelerated extraction of coal in order to meet 

the fuel requirement of coal based generating 

stations, was sent to Ministry of Power. The 

last two issues are under consideration of the 


9.12 Task Force on measures for 

Operationalization of Open Access 

Chairperson, CEA is a member of the Task 

Force set up by the Planning Commission on 

Operationalisation of Open Access. Member 

(E&C) and Economic Adviser participated in 

the meetings. Economic Cell provided inputs to 

facilitate deliberation of the Task Force. 

The Report of the Task Force was issued 

in January, 2009. The recommendations of the 

Task Force with respect to regulatory and system 

changes are: 

(a) Central and States’ ERCs should be advised 

by the appropriate government to comply 

with the statutory requirements relating 

to open access in a time bound manner. In 

particular, they must prescribe the open 

access surcharge in accordance with the 

provisions of the Tariff Policy notified by 

the Central Government under Section 3 of 

the Act. 

(b) The State Government should be advised 

to advise the States’ ERCs to specify the 

temporary connection charges to be charged 

by the Discom for providing standby supply 

in accordance with paragraph 8.5.6 of the 

Tariff Policy. 

(c) The States’ ERCs should conform to the 

provisions of Section 42(2) of the Act which 

requires them to provide open access to 

all consumers of 1MW and above within 

a period of five years from the coming 

into effect of the amendment of the Act in 

January 2004. 

(d) The State authorities should be advised to 

permit free sale of electricity and not compel 

generating stations to sell electricity to the 

SEB/Discom in the State except where a 

Power Purchase Agreement exists. 



(e) State Government and States’ ERCs should be 

suitably advised to enable operationalisation 

of open access to promote a healthy 

development of the market where private 

investment can be attracted. Where the State 

Government or the respective SERCs do 

not conform to the Act or the Tariff Policy 

thereunder, the State Government be advised 

and matter discussed in the appropriate inter 

and intra-State forum of Power Secretaries/ 

Ministers. 

(f) To enable competing suppliers to use the 

distribution network on a level playing 

field, the tariff for distribution companies 

should clearly specify the energy charges and 

wheeling charges separately. It is, therefore, 

recommended that the SERCs should be 

advised to specify wheeling charges and 

energy charges separately in conformity with 

Section 42 read with Section 62 of the Act. 

(g) Segregation of transmission and trading 

should be undertaken by all States in 

accordance with the letter and spirit of the 

Act and in a time-bound manner. 

(h) State Governments should be advised to 

set up SLDCs as independent entities with 

financial and operational autonomy. 

(i) SLDCs should be upgraded in a timebound 

manner to enable open access under 

Section 42. 

(j) SERCs should ensure other enabling 

arrangements such as standby supplies at 

affordable prices, metering and settlement. 

(k) IPPs, captive and small generating stations 

should be allowed to bring power into the 

market without any hindrance in grant of 

open access. 

(l) Regulators should meet with the bulk 

consumers and other stakeholders to address 

their concerns with a view to operationalizing 

the scheme of open access as provided in 

the Act. Consumer education and pro-active 

action by Regulators, both at the Centre 

and in the States, was considered vital for 

encouraging open access to consumers. 

9.13 Monitoring of National Electricity 

Policy-2005 

As per the provisions of Section 3 of the 

Electricity Act, 2003, the Central Government 

is required to prepare the National Electricity 

Policy and Tariff Policy in consultation with the 

State Governments and the Central Electricity 

Authority. The Central Government may also, 

from time to time, in consultation with the State 

Governments and the Authority review or revise 

the National Electricity Policy and Tariff Policy 

so prepared. CEA decided to monitor the Statewise 

progress on actionable points contained in 

the National Electricity Policy and Tariff Policy. 

CEA identified actionable points in the NEP 

and sent a questionnaire to all State Governments. 

Responses were received from 15 states. These 

were tabulated and uploaded in CEA website. 

Brief findings are listed below:- 

(i) Grid Code: As per the NEP, the SERCs are 

required to notify the Grid Code under the 

Electricity Act, 2003 not later than September 

2005. Out of the 14 States with SERCs, only 

one, viz. Madhya Pradesh had notified the 

Grid Code within the required timeline. As 

on their date of response, 5 States have not 

yet notified their State Grid Codes under the 

Electricity Act, 2003. 

(ii) Independent functioning of SLDCs: NEP 

has called attention to the fact that the spirit 

of the provisions of the Electricity Act is to 

ensure independent system operation through 

the Load Despatch Centres. However, 

no timeline for independent operation of 

SLDCs has been laid down in NEP. It is 

seen that SLDCs are still being operated by 


107


the State Transmission Utility in each of the 

respondent States. While some States have 

established SLDCs that are separate from the 

point of view of accounting and budgeting, 

operationally they continue to function under 

the State Transmission Utility. 

(iii) Initiation of Energy Audit and Declaration 

of Results: A time bound programme had to 

be drawn up by the SERCs for segregation 

of technical and commercial losses through 

energy audits. Energy accounting had 

to be conducted in each defined unit as 

determined by SERCs and its results had 

to be declared not later than March 2007. 

The responses received so far show that 

most of the discoms have only initiated 

action on energy audits. On the whole, 

however, results of energy audit have yet to 

be declared. Five States have reported that 

they have not yet initiated work related to 

energy audits. Some responses have also 

reported that while they are taking work on 

energy audits, they are not yet in a position 

to undertake segregation of technical and 

commercial losses. 

(iv) Open Access Charges: Charges related 

to open access on transmission and cross 

subsidy surcharge for users of the distribution 

system have been fixed by the SERCs in most 

of the respondent states. 

(v) Metering: The NEP lays emphasis on 

comprehensive metering. Incomplete 

information on this crucial issue from most 

states reveals that this issue is not being 

monitored with the sincerity and intensity 

it merits. 

● 11kV Feeders: Metering on 11kV feeders 

is complete or near completion in 8 of 

the respondent States. Of the remaining 

states, some discoms have reported 100% 

metering. 

● DTRs: The status of metering of distribution 

transformers is something that needs to be 

focused on in all the respondent States. The 

problems with respect to DTR metering 

could be a combination of technical, social, 

financial reasons. Policy should be addressed 

to finding solutions for problems that are 

common to a majority of states. 

● Consumers: On the issue of metering to 

individual consumers, most states have 

reported significant progress with Tamil 

Nadu and Kerala reporting 100% metering 

of individual consumers. However, metering 

of agricultural services is still to be achieved 

in most states including those which have 

reported 100% metering of non-agricultural 

consumers. This issue requires a policy 

focus. Alternative approaches such as feeder 

separation need to be debated. 

(vi) Standards for Loss Levels: Emphasizing 

the overriding importance of containing 

system losses, the NEP has required the 

SERCs to set standards for loss levels 

from time to time. CEA asked whether a 

long term trajectory for reduction of AT&C 

losses has been specified by the SERCs. Six 

of the 14 respondent States with regulatory 

commissions in place have said that such a 

trajectory has not yet been specified. 

(vii) Third party testing of consumer meters: 

SERCs were required to put in place 

independent third-party meter testing 

arrangements. This was meant to be a 

confidence building measure amongst the 

consumers and a mechanism to garner their 

support for the reform process. Seven out 

of 14 respondent states have not put this 

mechanism in place. 

(viii) SCADA: A time-bound programme for 

implementation of SCADA and data 

management system was to be obtained 



from the distribution licensees and approved 

by SERCs. Only Delhi has responded in the 

affirmative. This system is not in place in 

the distribution companies in any other 

State. While no time line is specified in 

the NEP for this purpose, it needs to be 

emphasized that the NEP states that these 

systems are useful for efficient working 

of distribution utilities. It is not clear 

why action on this essential efficiency 

measure has not been initiated in a timebound 

fashion. Reforms in the distribution 

segment need to be focused if the power 

sector is to turn around. 

9.14 Tariff Analysis 

During the Financial Year 2008-09, tariff 

orders in respect of Jammu & Kashmir for the 

year 2007-08, Bihar for the year 2008-09 and 

Uttaranchal for the year 2006-07 were received. 

CEA examined the above tariff orders in 

respect of issues relating to T&D Losses, Annual 

Revenue Requirement, Cross Subsidy, Cost of 

Supply, Power Purchase Cost, O&M Expenses, 

etc. Tariff Orders on Generation and Transmission 

were received from Madhya Pradesh and the same 

has been examined. 

9.15 Expenditure in Power Sector 

CEA obtained and collated the information 

to present a consolidated picture of the expenditure 

in generation, transmission and distribution 

segments of the power sector during financial year 

2007-08. A snapshot picture of expenditure in the 

power sector during 2007-08 is shown below: 

(Rs. in Crores at Current Prices) 

Sector Generation Transmission Distribution Total 

Thermal Hydro Nuclear 

Central 13501.87 3974.90 1886.00 6703.02 184.26 26250.05 

State 14560.63 1681.30 -- 7503.91 14010.34 37756.18 

Private 10590.52 1495.80 -- -- 1681.00 13767.32 

TOTAL 38653.02 7152.00 1886.00 14206.93 15875.60 77773.55 

Note:- 1. Investment in Thermal & Hydro projects benefiting 11 th Plan & 12 th Plan are included. 

2. Investment in UMPPs, CPPs and NCE and Renewables are not included. 

3. Investment in Transmission (220kV & above): shows actual investment (Data from BSEB and States from North-east 

except Assam and Meghalaya have not been made available) 

4. Investment in Distribution (33kV & below) includes only for 23 out of 35 States/UTs (54 out of 73 Discoms/ SEBs including 

UTs). Data from Bihar, Goa, Jharkhand, Kerala, Karnataka (2 discoms), Orissa (3 discoms), Sikkim, Arunachal 

Pradesh, Assam, Nagaland & Tripura, and UTs of Chandigarh, Lakshadweep & DNH have not been made available. 

9.16 Foreign Delegation 

A foreign delegation from Saudi Arabia led 

by Vice Governor for Regulatory Affairs visited 

India in last week of July 2008 for an introductory 

interaction to explore the possibility of initiating 

cooperation between India and Saudi Arabia in 

the field of Power. CEA agreed to encourage 

and facilitate joint cooperation in the following 

areas:- 

● 

● 

● 

● 

Regulatory issues related to the power sector 

including reforms and restructuring. 

Setting up of electrical equipment testing 

facilities in Saudi Arabia on the lines of 

Central Power Research Institute. 

Power Systems Planning, Design, Operation 

including Grid Management. 

Energy Conservation and Efficiency including 

Demand Side Management. 


109


● 

Development of power generation, 

transmission and distribution projects. 

T h e p r o p o s e d M e m o r a n d u m o f 

Understanding (MOU) has been agreed to by the 

Ministry of Power and referred to the Ministry of 

External Affairs for their concurrence and advise 

on mode of execution. 

9.17 Consultancies 

● Consultancy inputs were provided to 

Jharkhand State Electricity Regulatory 

Commission for appointment of Distribution 

Licensees in Ranchi. 

● Economic Cell prepared draft bid documents 

for appointment of consultant for Meghalaya 

for development of power projects in 

Meghalaya. 

9.18 Constitution of Electricity Regulatory 

Commissions (ERCs) 

All the States except Arunachal Pradesh 

have constituted their respective State Electricity 

Regulatory Commission (SERC). The States of 

Manipur & Mizoram have constituted a Joint 

ERC. All the SERCs except the SERC of Sikkim 

are functional. 

A separate Joint Electricity Regulatory 

Commission (JERC) has been constituted by the 

Central Government for Union Territories (except 

Delhi). On the request of Government of Goa, it 

has been decided to include the State in JERC 

for UTs (other than Delhi). The nomenclature of 

JERC for UTs has been changed to “ JERC for 

Goa and Union Territories. 

9.18.1 Constitution of Special Courts 

So far, 23 States viz. Assam, Andhra Pradesh, 

Chhattisgarh, Gujarat, Haryana, Himachal 

Pradesh, Jammu & Kashmir, Karnataka, Madhya 

Pradesh, Maharashtra, Meghalaya, Manipur, 

Nagaland, Orissa, Punjab, Rajasthan, Sikkim, 

Tamil Nadu, Tripura, Uttar Pradesh, Uttrakhand, 

West Bengal and Delhi have set up the Special 

Courts for expeditious disposal of cases relating 

to the theft of electricity. 

9.18.2 Constitution of Consumer Grievances 

Redressal Mechanism 

Consumer Grievances Redressal Forums 

(CGRF) have been constituted in 22 States by 

various distribution licensees for redressal of 

grievances of consumers. 

Ombudsmen have been appointed in 22 

States to look into the non-redressal of grievances 

by the CGRF. 

9.19 Assistance to Ministry of Power 

‣ Reply furnished on the reference regarding 

follow-up action on the announcement made 

by the Hon’ble Prime Minister in the 54 th 

NDC. 

‣ Reply furnished on the reference regarding 

summary record of discussion of the meeting 

of the Consultative Committee of Member 

of Parliament for Ministry of Power held on 

12.2.08 at Tehri HEP, Tehri, Uttrakhand. 

‣ Comments furnished on the reference from 

Planning Commission regarding 5 th Meeting 

of the Group to suggest a model set of bidding 

documents for the States in transmission of 

electricity. 

‣ Reply sent on the reference regarding minutes 

of the meeting of the Consultative Committee 

of Members of Parliament for MoP held on 

7.5.08. 

‣ Reply sent on the reference regarding 

Performance Audit Report on 

‘Implementation of Power Purchase 

Agreement” between Andaman & Nicobar 

Islands Administration and M/s Suryachakra 

Power Corporation Ltd. 




meeting of the full Planning Commission 

Draft Integrated Energy Policy. 


Assessment on State-wise impact of the 

Power sector on State finance over the next 

five years. 

‣ Reply sent on the reference regarding Minutes 

of meeting of the Consultative Committee of 

Members of Parliament for the Ministry of 

Power held on 18 th July, 2008 at Ranchi, 

Jharkhand. 


Question/issues concerning Power Sector. 

‣ Material furnished for the Annual Report of 

Ministry of Power for the year 2008-09. 

‣ Material furnished on the Economic Survey 

2008-09. 

‣ Comments furnished on Constitution of a Task 

Force as per the decision in CGAR meeting 

– Integrity Pacts: Types of Transaction & 

Threshold value. 

‣ Comments sent on the letter from Dr. P.C. 

Lunia, Chairman, Golden India Foundation, 

Jaipur on their Scheme for Energy forwarded 

by PMO. 

‣ Material furnished for inclusion in the 

President’s Address to both the House of the 

Parliament during the Budget Session for 

2009-10. 

‣ Material furnished for inclusion in Finance 

Minister’s Budget Speech for 2009-10. 

‣ Reply sent on “Standing Committee on 

Energy- Examination of Subject – “Power 

situation in the country with special reference 

to Development of Power Projects and future 

programme in regard thereto” during the year 

2008-09. 

‣ Reply sent on Revision of Union War 

Book, 1993 – Matter regarding provision 

in Electricity Act, 2003 for diversion of 

electricity. 

‣ Comment furnished on “Implementation of 

economic stimulus measures – Mtg. of the 

Cabinet Secretary with Chief Secretaries of 

the States on 13.3.09 and 16.3.09. 

‣ Reply sent on “Recommendations made 

by the 2 nd Amendment to Reforms 

Commission in the Fourth Report titled 

“Ethics in Governance” relating to ‘Reducing 

discretion’, ‘simplifying transaction’, 

‘promoting competition’ and ‘Ensuring 

Accessibility and Responsiveness’. 

9.20 Legal Assistance/Advice to Utilities 

‣ Comments furnished to the reference received 

from Chief Vigilance Officer regarding “ List 

of Undesirable Contract Men (UCM).” 

‣ Comments furnished on Legal aspects on the 

reference regarding Gundia Hydro-electric 

Project (2x200MW). 

‣ Comments furnished on the reference received 

from Chief Engineer(C&E) regarding Paper 

on Low Carbon Growth for Indian Power 

Sector. 

‣ Comments furnished on the reference 

regarding Detailed Project Report of Teesta 

Stage-IV Hydro Electric Project (4 x 130 

MW) in Sikkim by NHPC Ltd. 

‣ Reply furnished on “Information sought by 

Shri Bipil Chandra Chaturvedi, Delhi to PIO 

& Chief Engineer(EI) under RTI Act,2005. 

‣ Comments furnished on legal aspects on 

the reference regarding Detailed Project 

Report of Siang HEP (8 x 300 MW ) in 

Arunchal Pradesh by M/s Jaiprakash 

Power Venture Ltd. 

‣ Reply sent on the reference regarding 25 th 

Report on Demands for Grants (2008-09) of 

the Ministry of Personnel, Public Grievances, 

Law & Justice. 


111


‣ Reply sent on the reference regarding Power 

Summit – 2008 on 27 th September, 2008 

at Guwahati in partnership with Mr. Avjit 

Majumdar, North East Power News. 

‣ Detailed Project Report (DPR) of Domwe 

Lower HEP (1630 MW ) by Athena Demwe 

Power Pvt. Ltd. examined on legal aspects 

and comments furnished. 

‣ Reply sent on the reference from Gujarat 

Electricity Regulatory Commission regarding 

draft order in the matter of determination of 

cross subsidy surcharge under Intra-State 

Open access. 

‣ Reply on the reference from Shri Himadri 

Chakrabory, Advocate (Liquidator), High 

Court, Kolkata regarding non-payment of 

Award amount of Rs.13.81 lacs by BSEB to 

Sijua (JHERRIAN) Electric Supply Co. Ltd. 

was sent to them. 

‣ Comments furnished on the reference on Levy 

of Service Tax on Electricity Transmission 

and SLDC charges. 

‣ Comments furnished on the reference on 

Committee on Public Undertakings (2008- 

09) – Thirty Fourth Report on ‘Physical and 

Financial Performance of Power Generation 

PSUs. 

‣ Reply furnished on Request for waiver and 

release of Bank Guarantee furnished by 

Coastal Gujarat Power Ltd. 

‣ Comments furnished on Study Commissioned 

by ISCS on compensation to resource bearing 

States relating to the natural resources – 

minerals including coal, hydro power and 

petroleum and Natural Gas. 

‣ Material furnished regarding Proposal for 

inclusion in the study of Tariff Commission 

for the year 2009-10. 

‣ Comments furnished on - National Electricity 

Policy, National Tariff Policy & the Rural 

Electrification Policy. 

9.21 Court Cases 

Following court cases were dealt with:- 

‣ Writ Petition (Civil) 79/2005 filed in Supreme 

Court of India-Reg. Pollution by Thermal 

Power Plant. 

‣ Writ Petition (Civil) 328 of 1999 filed in 

Supreme Court of India-reg. Power Crisis in 

NCT of Delhi. 

‣ WP (C) 40/2005 by Shri N.B. Bhandari Vs. 

UOI,CEA and others in Sikkim HC. 

‣ Writ Petition No.211/2008 – in the High 

Court of Uttrakhand at Nainital between 

Bharat Jhunjhunwala Vs. NHPC & others. 

‣ Writ Petition (Civil) No.32588 of 2008–Kerala 

Electricity Employees Confederation Vs. 

Union of India & Others before the Hon’ble 

High Court of Kerala at Ernakulam. 

‣ Civil/Criminal Misc. Writ Petition No.1861 

of 2009 in the Allahabad HC. 

9.22 Re-organisation of States – Redressal 

of Grievances of Employees 

Following reorganization of States of Bihar 

(Bihar & Jharkhand), Madhya Pradesh (MP & 

Chhattisgarh) and Uttar Pradesh (Uttar Pradesh 

& Uttrakhand) the distribution of employee and 

their grievances are to be examined and decided 

by Chairperson, CEA as Appellate Authority. 

These cases have been examined and submitted 

for the approval of Appellate Authority. 

****** 



CHAPTER – 10 

POWER GENERATION 

10.1 Power Generation 

Generation of power in the utilities 

stood at about 723.80 billion units during the 

Year 2008-09. This represents the growth of 

2.74 % over the same period during previous 

year 2007-08 as per details given below: 

Category 

Programme 

(MU) 

Power Generation during 2008-09 

Actual 

(Tentative) 

(MU) 

Shortfall(-) / 

Excess (+) 

(MU) 

% of 

Programme 

% of last year 

(2007-08) 

Generation 

Hydro 118450 113081.16 (-)5369 93.48 105.57 

Nuclear 19000 14712.59 (-)4288 77.43 87.70 

Thermal 631270 590100.77 (-)41169 95.47 91.62 

Bhutan Import 5624 5899.10 (+)275 104.89 111.77 

Total All India 774344 723793.62 (-)50551 93.47 102.74 

It is seen from above table that during the 

year 2008-09, the total power generation was 

93.47% of the target. 

The main reasons observed for low growth 

in power generation are as follows: 

● Low generation in Nuclear Plants due to the 

fuel constraints. 

● Shortage of gas for operation of the existing 

gas based stations. 

● Loss of generation due to shortage of coal 

● Lower inflows at hydro stations due to low 

rainfall during the monsoon. 

● 

● 

● 

3454 MW capacity (excluding renewables) 

was added against the target of 110691 MW 

during 2008-09. 

Delay in achieving commercial operation/ 

commencement of full generation from some 

of the newly commissioned units due to noncompletion 

of balance of plant works. 

Shortfall in generation from some of the 

new thermal units due to initial stabilization 

problem. 

The sector wise PLF/Generation during 

2008-09 is given below: 

PLF (%) TARGET (MU) ACTUAL (MU) 

CENTRAL SECTOR 

THERMAL 84.3 260824 245961.09 

NUCLEAR 40.8 19000 14712.57 

HYDRO - 42912 43359.42 

TOTAL - 322736 304033.10 

STATE SECTOR 

THERMAL 71.2 304764 280477.88 

HYDRO - 70221 64496.91 

TOTAL - 374985 344974.79 


113


PVT SECTOR UTILITIES 

THERMAL 91.0 26383 26176.40 

HYDRO - 1586 1215..6 

TOTAL - 27969 27391.46 

PVT SECTOR IPPs 

THERMAL - 39299* 37485.40* 

HYDRO - 3731 4009.77 

TOTAL - 43030 41495.17 

BHUTAN IMPORT 

HYDRO - 5624 5899.00 

ALL INDIA 

THERMAL 77.2 631270 590100.77 

NUCLEAR 40.8 19000 14712.59 

HYDRO - 118450 113081.16 

BHUTAN IMPORT - 5624 5899.00 

TOTAL 774344 723793.52 

*Includes import from some of the Captive Plants 

10.2 Plant Load Factor of Thermal Power 

Stations 

During the year 2008-09, the average 

PLF of thermal and nuclear power plants was 

77.22 % and 40.77 % respectively. 

44 thermal stations achieved PLF higher than the 

All India average PLF of 77.22% as per details 

given in the table below: 

List of Thermal Power Stations which have achieved PLF above national average of 77.22 % 

during the year 2008-09 

Installed 

PLF 

Sl.No. Name of Stations State Sector Capacity 

(%) 

(MW) 

1. Dahanu TPS MAHARASHTRA Private 500 100.97 

2. Budge Budge TPS WEST BENGAL Private 500 100.53 

3. TOR. Power SAB TPS GUJARAT Private 330 100.38 

4. Dadri TPS UTTAR PRADESH Central 840 99.35 

5. Simhadri TPS ANDHRA PRADESH Central 1000 97.28 

6. Rihand STPS UTTAR PRADESH Central 2000 97.23 

7. Korba STPS CHHATTISGARH Central 2100 96.21 

8. GHTPS PUNJAB State 420 95.98 

9. Kota TPS RAJASTHAN State 1045 94.82 

10. Southern Repl WEST BENGAL Private 135 94.62 

11. Ramagundem TPS ANDHRA PRADESH Central 2600 94.45 

114 

“In order to live free and happily you must sacrifice boredom. It is not always an easy sacrifice.”


12. Unchahar TPS UTTAR PRADESH Central 1050 93.76 

13. Dr. N TATA RAO ANDHRA PRADESH State 1260 93.62 

14. Vindhyachal STPS MADHYA PRADESH Central 3260 93.15 

15. Rayalseema TPS ANDHRA PRADESH State 840 92 

16. Titagarh TPS WEST BENGAL Private 240 91.83 

17. Singrauli STPS UTTAR PRADESH Central 2000 90.71 

18. Talcher TPS ORISSA Central 470 90.71 

19. TOR. Power AEC GUJARAT Private 60 89.67 

20. Tanda TPS UTTAR PRADESH Central 440 89.4 

21. Korba East V CHHATTISGARH State 500 89.26 

22. Suratgarh TPS RAJASTHAN State 1254 88.99 

23. Badarpur TPS DELHI Central 705 88.48 

24. Mettur TPS TAMIL NADU State 840 87.68 

25. Trombay TPS MAHARASHTRA Private 1400 87.61 

26. Ropar TPS PUNJAB State 1260 87.08 

27. Khaparkhera II MAHARASHTRA State 840 87 

28. IB Valley TPS ORISSA State 420 86.78 

29. Korba-west STPS CHHATTISGARH State 840 86.6 

30. North Chennai TPS TAMIL NADU State 630 86.52 

31. Wanakbori TPS GUJARAT State 1470 86.27 

32. Talcher STPS ORISSA Central 3000 85.83 

33. Tuticorin TPS TAMIL NADU State 1050 85.34 

34. Ramagundem-B ANDHRA PRADESH State 62.5 85.27 

35. Neyveli (ext) TPS TAMIL NADU Central 420 84.99 

36. Sipat STPS CHHATTISGARH Central 1000 84.96 

37. Kothagundem TPS ANDHRA PRADESH State 500 83.52 

38. Anpara TPS UTTAR PRADESH State 1630 82.61 

39. Korba –II CHHATTISGARH State 200 82.41 

40. Raichur TPS KARNATAKA State 1470 81.59 

41. Panipat TPS HARYANA State 1360 80.57 

42. Korba –III CHHATTISGARH State 240 79.45 

43. GHTPS II PUNJAB State 500 79.12 

44. Gandhinagar TPS GUJARAT State 870 78.26 

It may be seen from the above table that 

three thermal stations recorded PLF exceeding 

100% viz Dahanu TPS-500MW(100.97%), 

Budge Budge TPS 500MW(100.53%) 

and Torrent Power Sabarmati TPS-330 

MW(100.38%). 18 thermal power stations 

with an aggregate installed capacity of 

20590 MW operated at PLF above 90%. 

All India Sector-wise/Organization-wise 

PLF, Thermal Generation, Target & Actual is 

given in the Annexure-10A. The trend in All 

India PLF from 1990-91 onwards is shown 

below: 


115


80 

75 

ALL INDIA THERMAL PLF(%) 

72.2 

72.7 

74.8 

73.6 

60 

76.8 

78.6 

77.2 

70 

67.3 

69 

69.9 

PLF (%) 

65 

61 

63 

64.4 

64.7 

64.6 

60 

55 

53.8 

55.3 

57.1 

50 

90-91 

91-92 

92-93 

93-94 

94-95 

95-96 

96-97 

97-98 

98-99 

99-00 

00-01 

01-02 

02-03 

03-04 

04-05 

05-06 

06-07 

07-08 

08-09 

Year 

10.3 Generating Capacity Addition 

During the year, a total of 3454 MW generation 

capacity was added which comprised 969 MW 

of hydro and 2,485 MW of thermal. The capacity 

addition during the last 7 years is given below:- 

Year Central Sector State Sector Private Sector Total 

2002-03 1210.00 1114.10 552.20 2876.30 

2003-04 3035.00 816.62 100.00 3951.62 

2004-05 2778.00 1571.32 70.00 4419.32 

2005-06 1370.00 1531.48 660.80 3562.28 

2006-07 4630.00 1693.00 551.80 6874.80 

2007-08 3240.00 5273.00 750.00 9263.00 

2008-09 750.00 1821.20 882.50 3453.70 

Note: i) During 2004-05, Uration in Hydro=50.40 MW & Nuclear=50 MW 

ii) During 2005-06, Upration in Hydro=24 MW & Nuclear=50MW 

iii) The above figures do not include Deration, Retirement and Installed Capacity of Renewable Energy 

Sources. 



Sector-wise generating capacity addition during 2008-09 is also shown in the chart below: 

Generating Capacity Addition During 2008-09 (3453.70MW) 

750 MW 

State 

Private 

Central 

882.50 MW 

1821.20 MW 

10.4 Installed Electricity Generation 

Capacity 

Total All India Installed Electricity 

Generation Capacity as on 31.3.2009 is 

Type 

Central Sector 

(MW) 

State Sector 

(MW) 

147965.41 MW comprising of Thermal 93725.24 

MW, Hydro 36877.76 MW, Nuclear 4120.00 

MW and 13242.41 MW from Renewable Energy 

Sources(RES). The details are shown in the 

Tables given below: 

Private Sector 

(MW) 

Total 

(MW) 

HYDRO 8592.00 27055.76 1230.00 36877.76 

THERMAL 36258.99 46812.23 10654.02 93725.24 

NUCLEAR 4120.00 0.00 0.00 4120.00 

RES 0.00 2247.68 10994.73 13242.41 

TOTAL 48970.99 76115.67 22878.75 147965.41 

State-wise/ Region-wise/ Sectorwise 

and prime mover-wise summary of 

installed capacity under utilities is given in 

Annexure-10B. The growth of installed 

generating capacity (reconciled) in the country 

is shown in the table below:- 

(Capacity in MW) 

Year 

(at the end of) 

Thermal Nuclear Hydro Wind* Total 

Dec.1947 854 - 508 - 1362 

Dec.,1955 1755 - 940 - 2695 

March, 1961 2736 - 1917 - 4653 

March, 1966 4903 - 4124 - 9027 

March, 1974 9058 640 6966 - 16664 

March, 1980 16424 640 11384 - 28448 

March, 1985 27030 1095 14460 - 42585 

March, 1990 43764 1565 18307 - 63636 


117


March, 1991 45768 1565 18753 - 66086 

March, 1992 48086 1785 19194 - 69065 

March, 1996 60083 2225 20986 - 83294 

March, 1997 61012 2225 21658 900 85795 

March, 1998 64005 2225 21904 968 89102 

March, 1999 67566 2225 22479 1024 93294 

March, 2000 70193 2680 23857 1155 97885 

March, 2001 72343 2860 25153 1270 101626 

March, 2002 74429 2720 26269 1628 105046 

March, 2003 76762 2720 26767 1628 107877 

March, 2004 77969 2720 29507 2488 112684 

March, 2005 80902 2770 30942 3812 118426 

March, 2006 82410 3360 32326 6191 124287 

March, 2007 86015 3900 34654 7760 132329 

March, 2008 91907 4120 35909 11125 143061 

March, 2009 93725 4120 36878 13242 147965 

Renewable Energy Sources (RES) includes Small Hydro Project, Biomass Gasifier, Biomass Power, Urban & 

Industrial Waste Power– for details see Annexure 10B 

Trombay Thermal Power Station 1000 MW (2×500 MW) of Tata's (Maharashtra) 

***** 

118 

“The one exclusive sign of thorough knowledge is the power of teaching.”



POWER DEVELOPMENT IN NORTH-EASTERN REGION 

11.1 Hydroelectric Potential in North- 

Eastern Region 

As per re-assessment studies carried out by 

CEA, hydro potential of the North-eastern Region 

in terms of installed capacity has been estimated 

as 58971 MW. Out of the above, 1202.7 MW have 

been harnessed so far while projects amounting 

to 2724 MW are under construction. The Statewise 

estimated hydro-electric potential of Northeastern 

Region and its status of development is 

given below: 

Region / State 

Identified potential 

as per Re-assessment 

Study (MW) 

Capacity Developed (Above 

3 MW Capacity) 

(MW) 

Capacity Under Construction 

(Above 25 MW 

Capacity) (MW) 

Meghalaya 2394 185.2 124 

Tripura 15 15 0 

Manipur 1784 105 0 

Assam 680 375 0 

Nagaland 1574 99 0 

Arunachal Pradesh 50328 423.5 2600 

Mizoram 2196 0 0 

Total 58971 1202.7 2724 

11.2 Survey & Investigation of Hydro 

Projects 

The Government has also approved a Three 

Stage Clearance procedure for hydro projects 

to be executed by CPSUs in consultation with 

MoF and MoEF. Under Stage-I, the CPSUs will 

incur expenditure on survey & investigation 

and preparation of Pre-feasibility Report. Under 

Stage-II, the CPSUs will undertake activities 

relating to detailed investigation and preparation 

of Detailed Project Report. During this Stage, 

pre-construction activities and infrastructure 

development including land acquisition will also 

be undertaken. Under Stage-III, approval of PIB/ 

CCEA would be sought for investment decision 

in respect of construction of the projects. 

11.3 Preparation of DPRs under 50,000 

MW Hydro Initiative 

Out of 62 (30416 MW) schemes for which 

PFRs have been prepared in respect of Northeastern 

Region, 25 schemes (22382 MW) whose 

first year tariff works out below Rs.2.50/kWh 

have been considered as low tariff H.E. schemes 

and have been selected for taking up of detailed 

survey & investigation and preparation of DPR / 

implementation. Out of these, DPRs in respect of 

five schemes namely Talong (160 MW), Dibbin 

(125 MW), Badao (60 MW), Mawhu (90 MW) 

and Demwe Lower (1630 MW) have already been 

prepared. The status of preparation of DPRs for 

H.E. projects in North-eastern Region is given 

at Annexure-11A. 


119


11.4 Mega Hydro Electric Projects planned 

in North-eastern Region 

The region presents very attractive sites 

for providing large storage with multi-purpose 

aspects of development. Major developments 

are under various stages in Siang, Subansiri 

and Dibang basins in Arunachal Pradesh and 

Tipaimukh (1500 MW) in Manipur. 

11.4.1 Siang basin projects – Arunachal 

Pradesh 

Due to large scale submergence and 

displacement of population involved in the 

original project proposal in the 4 km upstream of 

Rotung village in Arunachal Pradesh, the project 

was modified and divided into three separate 

schemes envisaging total capacity of about 13600 

MW in three power houses. Brief details of these 

three schemes are as under: 

Sl 

No. 

Name of the 

scheme 

Location 

(Distt./ 

Village.) 

Capacity 

(MW) 

Present Status 

1. Siang Upper/ 

Intermediate H.E 

Project 

Upstream of 

Yingkiong near 

Pugging village on 

Siang River 

East 

Siang/ 

Pugging 

11,000 Cost Estimates of NHPC for St-I activities were cleared by 

CEA on 14.03.2001. NHPC had earlier indicated I.C. as 11000 

MW. Subsequently two alternatives have been envisaged viz. 

Alt.-I (with 220 m high dam at upper location and a low dam 

at intermediate location) and Alt.-II (with 285 m high dam at 

intermediate location). Survey & Investigation by NHPC was, 

however, held up due to agitation by local people. 

Govt. of Arunachal Pradesh vide their letter dated 16.2.2009 

have entrusted NTPC with work relating to S&I and 

preparation of PFR for the project in order to study the 

possibility of developing the same in cascades to avoid 

submergence of important towns and settlements like 

Yingkiang and Tuting etc. 

2. Siang Middle 

H.E. Project 15 

km upstream of 

Raying near Roing 

village on the 

Siyom River which 

is a tributary of 

Siyom River 

West 

Siang / 

Roing 

1000 Cost estimates of St-II activities were cleared by CEA on 

21.02.2003. DPR of the project was submitted by NHPC 

in Sept., 2003 and returned by CEA in September, 2003. 

Environmental clearance was accorded by MoEF on 11.02.05. 

Subsequently, State Govt. allocated the project for execution 

on BOOT basis and an agreement in this regard was signed 

on 22.02.06 between Reliance Energy Ltd. & Govt. of 

Arunachal Pradesh. 

3. Siang Lower H.E. 

Project 

Upstream of 

Pasighat near 

Routung village 

Near 

Pasighat / 

Routung 

1600 Commercial viability of the project of NHPC was accorded by 

CEA on 25.03.2004. Site clearance (Stage-II) was accorded by 

MoEF on 18.08.2004. State Govt. has allocated the project for 

execution to IPP and MoA on BOOT basis has been signed on 

22.02.2006 between JP Associate Ltd. and Govt. of Arunachal 

Pradesh. Further in pursuance to tripartite agreement signed on 

13.12.2007, all aspects of obligation transferred to Jaiprakash 

Power Ventures Ltd. 



DPR submitted for installed capacity of 2400 MW was 

accepted for examination on 25.09.08. The same has been 

returned on 07.01.2009 for resubmission after modification 

in civil components and the installed capacity as suggested 

by CWC. 

11.4.2 Subansiri Basin Projects – 


The originally identified project 

envisaged installed capacity of 4800 MW. 

Subsequently, Govt. of Arunachal Pradesh 

accorded approval for development of 

three separate projects in place of earlier 

single project proposal in order to avoid 

submergence of Daporijo town and also 

to reduce displacement of people and to 

have minimal impact on the environment. 

The three separate schemes envisage total 

capacity of 5600 MW and are as under: 

Sl. 

No. 

Name of 

Scheme 

Location 

(District/ 

Village) 

Capacity 

(MW) 

Present Status 

1. Subansiri 

Upper H.E. 

Project. 

Upstream 

of Daporijo 

near Mengal 

village on 

Subansiri 

River. 

2. Subansiri 

Middle H.E. 

Project 

Upstream 

of Tamen 

village on 

Kamla river 

which is 

tributary of 

Subansiri 

river 

3. Subansiri 

Lower H.E. 

Project 

Gerukamukh 

village near 

original site 

on Subansiri 

River 

Upper 

Subansiri / 

Menga 

Lower 

Subansiri/ 

Tamen 

Lower 

Subansiri / 

Gerukamukh 

2,000 Cost estimates of NHPC for St-II activities in respect of Subansiri Upper 

and Subansiri Middle were cleared by CEA on 07.02.2003 and 4.2.2003 

respectively. However, S&I works for preparation of DPR in respect of 

these projects has been suspended due to non-availability of site clearance 

(Stage-II) which has been rejected by MoE&F on the basis of imposition 

of conditions by Indian Board of Wild Life (IBWL) in case of Subansiri 

Lower Project viz. banning of Upstream projects on Subansiri river 

and declaration of entire catchment of Subansiri as protected area. The 

same condition has also been reaffirmed by Hon’ble Supreme Court in 

its order dt. 21.04.2004. State Govt. has filed a writ petition in Supreme 

1600 Court for review of these conditions who has referred the matter to the 

Standing Committee of the National Board of Wild Life (NBWL) to 

consider waiving or modifying these conditions. The matter has been 

discussed by the Standing Committee of NBWL in various meetings 

held on the 10.9.07, 19.2.08, 22.5.08, 18.8.08 and 12.12.08 and it was 

recommended that 

i) Any proposal in respect of Subansiri river would be considered 

independently on its merit as and when submitted. 

ii) State Govt. would declare 168 sq. km. immediately as Sanctuary and 

would make serious efforts to bring additional 332 sq.km. reserve forest 

under the category of conservation reserve in consultation with MoEF. 

These recommendations were conveyed by MoEF vide letter dated 

12.1.2009 and shall be considered by Supreme Court for passing final 

orders. Thereafter, DPR for the project is to be submitted to CEA. 

2000 The project has been approved by CCEA on 09.09.2003 and is under 

construction by NHPC. The project is likely to be commissioned by 

2011-12. 


121


11.4.3 Tipaimukh Dam project (6x250= 

1500 MW) – Manipur 

Tipaimukh H. E. Project is a multipurpose 

project involving hydro power generation, flood 

control and irrigation. The scheme envisages 

construction of a dam across river Barak 

immediately downstream of the confluence of the 

Tuivai River. The scheme envisages an installed 

capacity of 6x250 MW. The project has been 

entrusted to M/s NEEPCO for execution. 

The project was techno-economically 

appraised by CEA in meeting held on 09.01.2003. 

Concurrence was accorded to the project vide CEA 

letter dated 2.7.2003 at an estimated cost of 

Rs.5163.86 crores at December 2002 price level 

including IDC of Rs.757.26 crores. Part estimate 

of Rs.9.52 crores for undertaking some works on 

priority under Stage-II activities of the project was 

recommended by CEA on 2.04.2004. 

Revised cost estimates of the project were 

cleared by CEA for an amount of Rs.6701.97 

crores including IDC of Rs.816.40 crores at 

December 2004 price level on 6.05.2005. This 

estimate also included additional provision of 

Rs.1100.78 crores as Net Present Value (NPV) @ 

Rs.5.8 lakh per Hectare of submerged forest land 

converted for non-forestry use. 

First PIB meeting was held on 25.10.2005. As 

per the minutes of the meeting, MoP had to submit 

a Supplementary Note to be studied and considered 

in the Core Group of the PIB for finalizing its 

recommendations. Second PIB meeting was held 

on 31.01.2006 which recommended the project for 

placement before CCEA for consideration, subject 

to the following observations: 

(i) Costs relating to flood moderation, diversion 

of National Highways and external security 

may be borne by the concerned administrative 

departments. The costs should be updated 

and availability of funds confirmed in the 

Note for CCEA. 

(ii) Ministry of Power may take up the issue of 

high NPV cost with the MoE&F and reflect 

the outcome in the Note for CCEA. 

(iii) Ministry of Power may persuade the State 

Governments of Mizoram and Manipur to 

reduce their share of free power from the 

project. 

(iv) Project costs may be updated to December 

2005 price level. 

(v) Ministry of Power would obtain Environment 

and Forest Clearance before submitting the 

proposal for consideration of CCEA. 

(vi) Risks relating to law and order and R&R to 

be explained clearly in the CCEA Note, along 

with strategies for risk mitigation. Views of 

Manipur and Mizoram Governments in this 

regard to be brought on record. 

(vii) PPAs may be firmed up before the project is 

submitted for consideration of CCEA. 

(viii) Adequacy of technical investigations, 

including critical design parameters, may be 

confirmed by the project authority to avoid 

any future surprises. 

As per PIB observations, following actions 

have been taken: 

(i) The updated revised cost estimates 

submitted by NEEPCO to CEA at Nov., 

2005 price level were vetted by CEA on 

22.03.2006 as Rs.5026.84 crores (as hard 

cost excluding IDC, flood moderation, 

diversion of National Highway and external 

security). Subsequently, CEA vetted the IDC 

component as Rs.828.99 crores (Nov. 2005 

price level) in August, 2006. Thus, the total 

cost at Nov., 2005 price level works out to 

Rs.5855.83 crores. This cost did not include 

the cost of flood moderation, diversion of 

National Highway and external security. 



(ii) In a meeting taken by Secretary (Power) 

on 26.2.2008 in MoP, NEEPCO indicated 

that MoWR on 15.12.2005 had conveyed 

approval for meeting cost of flood component. 

Ministry of Shipping, Road Transport and 

Highways conveyed their ‘In principle 

approval’ to meet cost of NH diversion on 

14.9.2006. MHA conveyed ‘In principle 

approval’ on 28.9.2006 of cost for providing 

external security with the mention that 

decision regarding this would be required to 

be taken by CCEA. 

(iii) The project has been accorded environment 

clearance on 24.10.2008. 

(iv) Regarding forest clearance, the Principal 

Chief Conservator Forest (PCCF), Govt. 

of Manipur forwarded revised proposal 

for diversion of forest land to the Under 

Secretary (Forest & Environment.), Govt. 

of Manipur for onward transmission to the 

Asstt. Inspector of Forests, MoE&F, on 

05.01.09. Regarding forest clearance from 

Mizoram, the matter is being pursued with 

the Revenue & Forest Department, Govt. of 

Mizoram. 

11.4.4 Dibang Multipurpose Project- 

(12x250 = 3000MW) – Arunachal 

Pradesh 

Dibang Multipurpose Project located on 

Dibang River in Lower Dibang Valley district of 

Arunachal Pradesh has been conceived to provide 

flood moderation benefits to the downstream areas 

of the project besides power generation. The 

scheme envisages an installed capacity of 3000 

MW. 

As per decision taken in a meeting held 

in July, 2006 between Hon’ble Chief Minister 

of Arunachal Pradesh and Hon’ble Minister of 

Power, an MoU for execution of the project as 

a joint venture was signed between NHPC and 

Govt. of Arunachal Pradesh on 21.09.2006. Later, 

a MoA was signed on 24 th June, 2007 between 

Govt. of Arunachal Pradesh and NHPC for 

execution of the project by NHPC on ownership 

basis without any equity participation by the State 

Govt. 

CEA accorded concurrence to the project on 

23.1.2008. The estimated present day cost of the 

project at Nov., 2007 price level including IDC 

and FC without provision for external roads and 

bridges is Rs.15886.39 crores and with external 

roads and bridges is Rs. 16425.65 crores. 

The project was considered at PIB meeting 

held on 28.1.2008. As per minutes of meeting 

circulated by MoP on 27.2.2008, the project was 

recommended for posing to CCEA for approval 

of Rs.15886.39 crores without provision of cost 

component for external roads and bridges subject 

to following conditions. 

1. Possibility of funding through external debt 

and subordinate debt may also be explored 

to reduce the cost of the project. 

2. The cost of external roads, bridges and 

providing flood moderation benefits should 

not be loaded to the project cost. 

3. The construction period of 9 years needs 

to compressed so that the benefits from the 

project could accrue much earlier, thereby 

resulting in reduction in IDC and FC 

charges. 

4. The difference between base cost and 

completion cost of the project seems to be 

on higher side as compared to other Hydro 

Projects, which needs to be examined 

further. 

The PIB suggested that a committee should 

be set up, as was done in case of Kishanganga HEP, 

to examine the aspects related to reduction in the 


123


cost of the project including difference between 

base cost and completion cost, funding through 

external and subordinate debt and exploring the 

possibility of reducing the construction period 

of nine years. The committee shall finalize the 

report which will be taken into consideration 

while preparing the Note for CCEA. Meanwhile, 

environment, forest and other statutory clearances 

for the project may also be obtained to facilitate 

posing of the project to CCEA for Investment 

Approval. 

In pursuance of PIB meeting, a Committee 

was set up by MoP on 23.4.2008 which submitted 

its report with the following recommendations: 

(a) Considering remoteness of the place, present 

infrastructure, future development to be 

undertaken, etc. compression of construction 

period is not feasible. 

(b) Keeping in view the location of the project 

(border State), stipulated conditions being 

imposed by foreign funding agencies and the 

national security concern, external funding is 

not taken into consideration. 

(c) There is energy generation loss of about 

880 MU due to flood moderation. The cost 

of flood moderation should to be borne by 

MoWR. 

(d) Rate of interest on loan to be considered as 

11% instead of 11.5%. The cost of project 

was recommended as Rs.14892.04 crores as 

against Rs.15886.39 crores (without external 

roads) as cleared by CEA. In the report, 

the cost apportioned to flood moderation 

component was taken as Rs.1107 cores. 

MoWR vide their letter 28 th August, 2008 

forwarded their recommendation on cost of 

flood moderation component for Dibang MPP as 

Rs.1074 crores. NHPC on 22.9.2008 intimated 

that the total cost of the project at Nov., 2007 

price level considering grant of Rs.1074 crores 

for flood moderation works out to Rs.14905.21 

crores including IDC and FC of Rs.1916.43 

crores. 

The environment and forest clearances in 

respect of the project are yet to be obtained. 

11.5 12 th Plan Hydro Projects 

Action has been initiated to take up / 

complete survey & investigation / DPR preparation 

and other construction activities well in advance 

so as to achieve the ambitious programme of 

capacity addition in the future Plans. Accordingly, 

a shelf of 31 candidate projects with an installed 

capacity of about 11798 MW has been prepared 

for North-eastern Region. 

11.6 Status of Various Hydro Power 

Projects in North-Eastern Region 

11.6.1 Central Sector Projects 

(A) Sanctioned Projects 

(i ) Tuirial HEP (2x30 = 60 MW), Mizoram, 

NEEPCO 

The project was approved in July, 1998 

at an estimated cost of Rs.368.72 crores 

with likely completion by 2006-07. This 

project was under execution with loan 

assistance from JBIC and presently under 

hold due to poor law & order conditions 

and intensive agitation by claimants 

of crop compensation. Continuation 

or otherwise of the project is being 

reviewed due to increase in the project 

cost to about Rs.686.95 crores making the 

power tariff very high. The resumption 

of work is dependent upon viability of 

the project, which is under consideration 

of the Govt. The project cost is financed 

substantially under loan assistance of 

11695 Million Japanese Yen from Japan 



Bank of International Co-operation 

(JBIC). 

(ii) Kameng HEP (4x150 = 600 MW), 

Arunachal Pradesh, NEEPCO 

The project was approved in December 

2004 at an estimated cost of Rs.2496.90 

crores (at March 2004 price level) with 

completion in 5 years. Now, the revised 

commissioning schedule is December 2011 

to March 2012 at an interval of one month 

each. Bichom dam work is in progress. An 

expenditure of Rs.860.38 crores has been 

incurred up to March 2009. CEA officers 

visited the project site in Nov. 2007 and 

advised NEEPCO that HRT works in Phase- 

II and Bichom Dam works are critical and 

needs extra efforts by NEEPCO and the 

contractors. 

(iii) Loktak Down Stream (66 MW), Manipur, 

NHPC 

The project, to be executed by NHPC, was 

cleared by CCEA for an Installed Capacity 

of (3x30=90 MW) on 31.12.1999 at an 

estimated cost of Rs.78.62 crores including 

IDC of Rs.46.95 crores (April 1999 price 

level). The environmental clearance was 

granted by MoEF on 4.2.99 and forest 

clearance on 3.1.97. 

The project is now proposed to be executed 

by a Joint Venture between NHPC and 

Government of Manipur with revised capacity 

of 66 MW. CEA accorded concurrence on 

15.11.2006 to the revised proposal. 

MoU has been signed between Government 

of Manipur (GoM) and NHPC on 14.9.2007 

for execution of this project on Joint Venture 

basis. As per MoU, the GoM has to arrange 

an amount of Rs.100 crores from the Ministry 

of Development of North Eastern Region 

(M/o DONER) for this project. In addition, 

if the GoM is able to arrange an additional 

grant of Rs.100 crores for the project from the 

Ministry of Finance/Planning Commission, 

it will be entitled to 12% of the power 

generated by the project free of cost. 

Commitment for grant of Rs.100 crores from 

M/o DONER has been received whereas 

the commitment for grant of Rs.100 crores 

from the Ministry of Finance/Planning 

Commission is yet to be received by GoM. 

Promoter’s agreement has been signed 

between NHPC and Govt. of Manipur on 

26.9.2008. 

(iv) Subansiri Lower (8x250=2000 MW), 

Arunachal Pradesh, NHPC 

Project was approved in September 2003 

for Rs.6285.33 crores to be executed by 

NHPC and is scheduled for completion by 

September 2010. Major civil, E&M and 

hydro-mechanical works have been awarded. 

River diversion achieved on 25.12.2007. 

Civil works of head race tunnel, pressure 

shaft, surge chamber and power house are 

in progress. MoU with State Government 

is yet to be signed. The project is now 

likely to be commissioned by December 

2012. Work progress suffered recently due 

to power house back hill slope failure and 

consequent disruption of access to Dam & 

Intake. Surge shafts have been modified to 

surge tunnels and the contract for the same 

has been awarded to M/s L & T Ltd. 

(B) CEA Cleared Projects 

(i) Tuivai H.E. Project (3x70=210 MW) in 

Mizoram cleared for Central Sector and 

transferred to State Sector 

The scheme was considered in concurrence 

meeting of CEA and concurrence letter was 

issued on 19.2.1999. The present day cost 

at March 1997 price level was Rs. 964.22 

crores including IDC component of Rs.47.31 

crores. The completed cost was estimated as 


125


Rs.1258.84 crores including IDC of Rs.58.89 

crores. 

NEEPCO submitted revised cost estimates of 

the project in July 2003. CEA vide its letter 

dated 28.05.2004 approved an amount of 

Rs.1122.51 crores (April 2003 price level) 

including IDC component of Rs.15.18 crores. 

Design energy of 620.82 GWh has been 

taken corresponding to TG efficiency of 92% 

(instead of 87% taken at the time of TEC). 

As per minutes of meeting taken by Secretary 

(Power) on 12.01.2006, at the request of the 

State Govt. of Mizoram, Ministry of Power/ 

NEEPCO agreed to hand over the project 

to the State Government. Besides, it was 

suggested that State Govt. may consider 

making NEEPCO a Joint Venture partner. 

The decision of State Govt is awaited. 

(ii) Pare Hydro Electric Project (2x55=110 

MW) in Arunachal Pradesh 

Pare HEP located in Papumpare District of 

Arunachal Pradesh was accorded concurrence 

of CEA on 24 th Sept. 2007 for an estimated 

present day cost of Rs.553.25 crores including 

IDC & FC of Rs.49.26 crores at June 2007 

Price Level. 

CCEA approval has been accorded to the 

project on 4.12.2008 for Rs.573.99 crores 

including IDC of Rs.67.66 crores and FC of 

Rs.0.40 crores at June, 2007 price level. The 

completion cost considering 44 months as 

construction period is estimated as Rs.674.45 

crores including IDC as Rs.76.52 crores and 

FC as Rs.0.47 crores. 

11.6.2 State Sector Projects 

(A) Sanctioned Projects 

(i) Myndtu Leshka H.E. Project (2x42+1x42 

MW=126 MW) Meghalaya 

Myntdu Leshka HE Project Stage-I is 

located in Meghalaya and is a run-of-river 

type scheme and envisages utilization of 

waters of river Myntdu with its tributaries 

Lamu and the Umshariang river. Work 

order of Main Dam has been awarded 

to M/s SEW Construction Pvt. Limited, 

Hyderabad in March 2004. Works of HRT 

allotted to M/s Skanska Cementation (I) 

Ltd., Kolkata in February 2005. E&M 

works awarded to VA Tech. India Pvt. Ltd. 

in November 2005 for Turbine, Generator 

and Computerized Control System (CCS). 

Power House (civil works), Tail race works 

were awarded to M/s SEW Construction 

Ltd., Hyderabad in February, 2006. Hydromechanical 

works (gates) awarded to M/s 

Precision, Ahmedabad in December 2005. 

Main step-up transformers awarded to M/s 

Vijay Electrical Ltd. EOT works awarded 

to M/s WMI Crane Ltd., Mumbai in May 

2006. The construction activities are now 

in advanced stage of completion. With 

best efforts, the Unit-I is expected to be 

commissioned in December 2009, Unit- 

II in February 2010 and Unit-III by June 

2010. 

(ii) New Umtru H.E. Project (2x20=40 MW), 

Meghalaya 

The New Umtru HE Project across river 

Umtru in Meghalaya is being executed 

by Meghalaya State Electricity Board 

(MeSEB). The project was approved by 

MeSEB at an estimated cost of Rs.194.3 

crores. Package-I-Civil works has been 

awarded to ITD Cementation Pvt. Ltd. 

in December 2007. Package-II Hydromechanical 

works has been awarded to 

M/s SEW Texmaco in January 2009 and 

Package-III Electro-mechanical works to 

M/s VA TECH Hydro in February 2009. 

The units are expected to be commissioned 

in January/ March 2012, provided work 

on all fronts is expedited by the project 

authorities. 



(B) CEA cleared Projects 

(i) Bairabi Dam (2x40=80 MW), Mizoram, 

by Power & Electricity Deptt, Govt. of 

Mizoram 

The project, to be executed by Power and 

Electricity Department, Mizoram, was 

given concurrence by CEA at an estimated 

completed cost of Rs.549.43 crores (including 

IDC of Rs.13.99 crores) and present day 

cost of Rs.441.67 crores (including IDC of 

Rs.11.25 crores) at March 2000 price level 

on 9.11.2000. 

As informed by Govt. of Mizoram, at the 

time of examination of DPR, funds for the 

project were proposed to be provided by 

Govt. of India as Central Assistance with 

terms and conditions of assistance to be 

governed by the rules followed in case of 

special category State i.e. 90% grant & 10% 

loan (with simple interest @ 10%). However, 

no Letter of Commitment from Govt. of India 

or Comfort Letter to this effect was made 

available to CEA. CEA found this project to 

be viable in case the project was funded on 

the aforesaid basis (90% grant). In the event 

of any change in the funding pattern, the 

project would require a fresh examination 

and Techno-economic Clearance for which 

the Govt. of Mizoram should revert back 

to CEA. One of the conditions stipulated 

in TEC letter was that if time gap between 

TEC and actual start of work is more than 3 

years, a fresh TEC of the project would be 

required. 

Proposal for funding the project through 

various agencies was being pursued by the 

State Govt. On the request of State Govt., 

validity of TEC had been extended six times, 

last one being up to 8.11.2007. 

Govt. of Mizoram on 21.08.2007 requested 

for further extension of TEC indicating that 

Mizoram was seeking Viability Gap funding 

for the project. CEA observed that during 

the last seven years, more hydrological data 

would have become available necessitating 

reassessment of power potential. As the 

cost estimates were more than 7 years old, 

they needed revision. Moreover, Govt. of 

Mizoram proposed to adopt public-private 

partnership mode for implementation of the 

project, which would change the funding 

pattern as well as executing agency. Taking 

these factors in view, CEA did not consider 

it appropriate to grant further extension of 

validity of TEC. The Govt. of Mizoram 

was informed accordingly vide CEA letter 

dated 1.10.2007. 

11.7 Status of Construction of Thermal Power 

Projects in North-Eastern Region 

(a) 

Lakwa Waste Heat Recovery Project 

(ST-37.2 MW), Assam 

The project is being executed by Assam 

Power Generating Co. Ltd. in the Sibsagar 

District of Assam State. EPC contract was 

placed with M/s BHEL on 20/03/2006. EPC 

contract for Raw Water intake pump house 

and Raw Water piping from River Desang 

to Lakawa TPS has been signed on 16/07/07 

with M/s Santosh Sahewalla, Sivsagar. The 

BHEL’s sub-contractor is working with 

inadequate manpower due to which the 

progress on civil construction front is very 

slow. STG building and TG deck are yet 

to be completed. EOT crane vendor has 

not yet been finalized. In absence of civil 

works, switchyard, GT & ST works are 

being delayed. The synchronization of ST is 

planned for Dec 09 and COD for Feb’ 10. 

(b) Bongaigaon TPS (3x250MW) 

The project is being executed by M/s NTPC 

at Salkati, Kokarjhar District of Assam. The 

MoE&F clearance has been obtained and 


127


(c) 

coal linkage for the project has been accorded 

by Ministry of Coal. Order of main plant 

package has been placed with M/s BHEL on 

05.02.2008. The latest approved cost of the 

project is Rs.4375.35 crores. Orders for main 

plant civil works, CW system civil works, 

water treatment plant, supply & erection of CW 

system, DM Plant, Chimney, LT Switchgear, 

400 kV switchyard and fire protection system 

have been placed. The boiler erection work is 

getting delayed due to incompletion of boiler 

foundations. The Railway siding work has 

been awarded to M/s RITES. The activity of 

drum lifting is planned for September 2009. 

Anticipated date of synchronization of unit is 

15.11.2010 and COD is 15.02.2011. 

Tripura CCPP (2x 363.3 MW) 

The project is being executed as joint 

venture of M/s ONGC, Govt. of Tripura 

& Infrastructure Leasing And Finance 

Services (IL&FS) at Palatana of Udaipur 

district of Tripura. MoE&F clearance 

and other clearances for the project have 

been obtained. Gas sale and purchase 

agreement between M/s ONGC and OTPC 

has been executed. Total estimated cost 

of the project is Rs.3429 crores. Main 

plant order has been placed on M/s BHEL 

on 23.06.2008. Zero date of project is 

23.06.2008. The order for BOPs has been 

awarded to M/s BHEL under Trunkey EPC 

contract. Leveling and boundary wall work 

at site has been started. The anticipated 

date of commissioning schedule of the 

project is January 2012 for Block I and 

April 2012 for Block II. 

11.8 Detailed Status of New Thermal Power 

Projects in North-eastern States 

Details of New Thermal Power Projects in Northeastern 

States is enclosed as Annexure-11B. 

11.9 Hydro Power Stations 

Eight (8) existing hydro schemes of Northeastern 

Region with an aggregate installed 

capacity of 494 MW have been identified for 

R&M works to accrue a benefit of 100 MW. 

The R&M activities of 4 schemes have already 

been completed at an actual expenditure of 

Rs.105.68 crores to accrue a benefit of 61 MW. 

The remaining 4 schemes are under various stages 

of implementation and are likely to be completed 

during the 11 th Plan to accrue a benefit of 39 MW 

at an estimated cost of Rs. 176 crores. 

The scheme-wise status of the R&M works 

of the hydro schemes of North-eastern Region as 

on 31.03.2009 is shown below:- 

S. No. Name of Scheme, Installed Cap. Cost (Rs. Benefits 

Status 

Agency, State (MW) in Crs.) (MW) 

1. Khandong, U-1, 

NEEPCO, Meghalaya 

1x25 0.62* 25 U-1 Restoration works completed 

in 1991-92 

2. Gumti, TSECL, Tripura 3x5 17.50* - R&M works completed in 1994- 

95 

3. Khandong, NEEPCO, 

Meghalaya 

2x25 3.35* - R&M works completed in 2003- 

04 

4. Umium St.I MeSEB, 

Meghalaya 

4x9 84.21* 36 RM&LE works completed in 

2002-03 

5. Loktak, NHPC, 

Manipur 

3x30 

(Derated) 

19.25@ 15 R&M and Restoration works are 

ongoing. Likely to be completed 

by 2009-10 



6. Umium St.II, MeSEB, 

Meghalaya 

7. Kopili, NEEPCO 

Assam 

8. Kyrdemkulai, MeSEB, 

Meghalaya 

9. Khandong, NEEPCO, 

Meghalaya 

*= Actual, @ = Estimated 

11.10 Installed Capacity in the N.E. 

Region 

The total installed capacity in the Region is 

as under: 

Sector Installed Capacity (MW) 

Hydro 1116.00* 

Thermal 968.74** 

RES 171.00 

Nuclear 0.00 

Total 2255.74 

* Excluding small hydro schemes covered 

under Renewable energy Sources. 

** Excluding 110 MW share from 

Kahagaon TPS of Eastern Region 

11.11 Identification of Candidate Hydro 

Projects for 12 th Plan 

Action has been initiated to take up / complete 

their survey and investigation / DPR preparation 

and other construction activities well in advance so 

as to achieve the ambitious programme of capacity 

addition in the coming Plans. Accordingly, a shelf 

of 31 candidate projects with an installed capacity 

of about 11798 MW has been prepared for Northeastern 

Region. 

2x9 90.46@ 18 RM&LE works yet to commence. 

JBIC funding. Likely to be 

completed by 2011-12 

2x50 + 

2x50 

66.42@ - The NEEPCO was advised to float 

tenders for R&M works as BHEL, 

the OEM not submitted their offer 

inspite of continuous precautions. 

Likely to be completed in 2011- 

12. 

2x30 168.00@ 66 RM&U works to commence after 

completion of Umium Stage-II 

works. DPR under preparation. 

Likely to be completed in 12 th 

Plan. 

2x25 5.00@ 50 R&M works yet to commence 

11.12 Hydro Power Generation Performance 

Hydro generation during 2008-09 in the 

North-eastern Region was 4587 MU against 

a target generation of 4895 MU resulting in a 

shortfall of 308 MU due to less inflow during 

the monsoon. 

11.13 DONER Schemes 

Following works were completed during 2008-09: 

(i) Technical clearance of the scheme for 

Installation of 33/11 kV, 2x5 MVA S/S 

along with associated 33 kV line at Ukhrul 

Khunjao in Manipur under NLCPR 

(ii) Technical clearance of the scheme for 

Installation of 33/11 kV, 2x5 MVA S/S along 

with associated 33 kV line at Sekmaijin in 

Imphal West district in Manipur under 

NLCPR 

(iii) Technical clearance of the scheme for 

Installation of 33/11kV, 2x3.15 MVA 

S/S along with associated 33 kV line 

at Sagolmang in Imphal East district in 

Manipur under NLCPR 

(iv) Technical clearance of the scheme for 


129


Installation of 33/11kV,2x1 MVA S/S along 

with associated 33 kV line at Henglep in 

Churachandpur district in Manipur under 

NLCPR 

(v) Technical clearance of the scheme for 

Installation of 33/11kV,2x1 MVA S/S along 

with associated 33 kV line at Chakpikarong 

in Chandel district in Manipur under 

NLCPR 

(vi) Examination of the scheme for Erratic Power 

supply in Tripura University Campus 

(vii) Examination of DPR for Improvement and 

widening of Guwahati Garbhanga Road 

from Guwahati Shillong road at Paltanbazar 

to National Highway No 37 at Lakhara in 

Kamrup District under NLCPR. 

11.14 Status of Rural Electrification in 

North-eastern Region 

During 2008-09 (upto Feb., 2009), 18 of 

inhabited villages have been electrified and 165 

pumpsets have been energized. Cumulatively, 

29657 inhabited villages constituting 73.5% have 

been electrified out of a total of 40377 inhabited 

villages and 8773 pump sets have been energized 

in the North-eastern States. 

11.15 Development of Transmission, 

Sub-transmission and Distribution 

System in NER 

As a follow up action to Passighat 

Proclamation, Ministry of Development of North 

Eastern Region in consultation with Ministry 

of Power constituted a Sub-group-I under the 

Chairmanship of Shri V. Ramakrishna, Member 

(Power Systems), Central Electricity Authority 

to devise a methodology for extending technical 

and financial assistance on transmission, subtransmission 

and distribution related issues in 

North East Region (NER) on 22-2-07. The report 

with proposed recommendations of the Sub-group 

was prepared and forwarded to Secretary, M/o 

DONER, MoP and Member (Power), Planning 

Commission in December 2007. 

To implement the accelerated development 

programme in a focused manner, a phased 

programme has been evolved by Sub-group-I for 

the next 10 years. The programme is proposed in 

three phases: 

Phase-I (2007-11) 

Phase-II (2011-14) 

Phase-III (2014-17) 

Summary of total ckt. km and MVA for three 

phases is tabulated below: 

132kV, 220kV and 400kV - PHASE-I+II+III 2007-17 

State 

Nr of line 

ckts 

ckt kms of 

lines 

Nr of new 

s/s 

MVA of trf incl 

aug/repl 

Estimated 

Cost Rs 

Crores 

Arunachal 132kV 22 1210 16 410 600 

Assam 220kV 5 140 1 600 130 

Assam 132kV 89 2430 61 3400 1710 

Manipur 132kV 19 490 7 575 290 

Meghalaya 132kV 24 560 17 1450 450 

Mizoram 132kV 10 280 4 450 170 

Nagaland 132kV 11 220 4 550 160 

Tripura 132kV 26 930 13 890 510 



Sikkim 132kV 13 410 7 500 250 

Inter State 400kV 26 3260 6 4035 3820 

Inter State 220kV 14 570 6 1340 510 

Inter State 132kV 22 890 6 350 400 

Total 281 11390 148 14550 9000 

It is proposed to build Intra-State and Inter- 

State Transmission schemes with 90% grant and 

10% loan. For execution of the schemes, funds are 

required to be tied up with M/o DONER / Planning 

Commission. To meet system requirements of the 

NER States optimally, intra-state and inter-state 

transmission development programmes were 

subsequently retuned in consultation with NER 

States and PGCIL. PGCIL has been entrusted to 

prepare DPR for transmission, sub-transmission 

and distribution system upto 11kV as decided by 

MoP and M/o DONER. The estimated expenditure 

for preparation of DPR is Rs. 50 crores. 

For a period upto 11 th Plan (March 2012), 

priority schemes for inter-State and intra-State 

transmission works have been identified and 

forwarded to the Planning Commission for 

tying up of the funds. The estimated expenditure 

involved for the same is as follows: 

ISTS - Rs. 2320 crores 

Intra-State Rs. 2030 crores 

ST&D Rs. 2000 crores 

PGCIL has already taken up works for the 

development of ISTS portion through its own 

source and Planning Commission is considering 

converting some portion into grant. With regard 

to Rs.2030 crores for the intra-State portion, 

Planning Commission would provide the entire 

funding. As far as Rs.2000 crores required for 

ST&D, it should be met mostly from APDRP, 

RGGVY and balance funds would be provided 

by Planning Commission. 

Vijayawada Thermal Power Station 1260 MW (6×210 MW) in AP 

***** 


131



TRAINING AND HUMAN RESOURCE DEVELOPMENT 

12.1 Training of Manpower in CEA 

As Human Resource is an essential 

component for carrying out any business or 

service of an organization, it is required to be 

developed to produce a quality product/service 

at a reasonable price. To attain this objective, the 

technical, managerial and behavioral competence 

of the human resources are developed and 

enhanced through training. Keeping this objective 

in view, HRD, CEA has been organizing various 

training programmes in technical, managerial, 

IT, health and other areas to keep them abreast 

of technology and bringing about attitudinal 

change in consonance with the need of rapidly 

changing era of globalization. HRD has also been 

making efforts to keep stock of the infrastructure 

available for the development of human resources 

in the power sector. CEA has been following up 

with the utilities/organizations on the status of 

implementation of the National Training Policy 

for the power sector. To fulfill its statutory role 

under Rule 3 of IE Rules 1956, CEA has been 

sending teams to visit power sector institutes 

for their evaluation in terms of infrastructure, 

utilization and quality of training programmes 

and facilitate CEA accreditation for them in 

line with the CEA Guidelines for recognition of 

training institutes for power sector. CEA has been 

advising/recommending various measures to the 

Training Institutes of Power Sector organizations 

for improvement in the training infrastructure 

and methodologies for enhancing the skills and 

productivity of the personnel. 

It has been the motto of CEA management 

to impart at least one week training annually to 

each employee of CEA. 

12.1.1 Management Development & 

Refresher Training Programme 

The management development programmes 

for CEA personnel at various levels in the relevant 

fields of specialization conducted at professional 

institutes of national and international repute 

like IIM, Ahmedabad/Bangalore, MDI Gurgaon, 

ASCI, Hyderabad were organized. 

The officers/officials were deputed for 

various in- service refresher training programmes, 

technical courses, workshops, seminars, 

conferences etc. at PMI, Noida, ASCI, Hyderabd, 

ISTM, New Delhi & CSMRS, New Delhi. 

The programmes organized for enhancing the 

managerial and interpersonal skills and for 

awareness about good health included the topics 

such as effective communication for managers and 

leaders, Right to Information Act, communication 

and listening skills, yoga, physical and mental 

exercise, motivation, leadership and team 

building, stress management, etc. The total man 

days for the above programmes were 4400. 

12.1.2 Induction Training for Direct 

Recruits, Assistant Directors 

Grade-I 

An induction-level training was imparted 

to twenty (20) direct recruit Assistant Directors 

Grade-I who joined CEA through UPSC and 

5 departmental Asstt. Directors-I. The training 

was organized for a period of 10½ weeks 

from 16 th January 2009 to 27 th March 2009. 

The training course comprised training of 5½ 

weeks at Engineering Staff College of India 

(ESCI) in Hyderabad, two weeks of simulator 

training at the National Power Training Institute 



(NPTI) in Faridabad and two weeks program of 

familiarization with various Divisions of CEA at 

CEA Headquarter, New Delhi, followed by one 

week program in Office Procedure in Government 

of India at the Institute of Secretariat Training and 

Management (ISTM), New Delhi. The technical 

training at the ESCI was interspersed by visits to 

the plants/ sub-stations. This provided opportunity 

to the officers of CEA to gain practical insight into 

the constructional and operational aspects of the 

power plants and Transmission & Distribution 

systems. 

12.1.3 Mid Career Training for Deputy 

Directors 

59 Deputy Directors of CEA were imparted 

a mid-career training of two weeks to refresh 

their technical knowledge covering a whole 

gamut of topics including latest technological 

advancements and regulatory and statutory 

mechanism for the development of the power 

sector. The ESCI, Hyderabad was roped in to 

conduct this course at Hyderabad. The training 

also involves visits to various power plants, 

substations and manufacturing establishments. 

The training was organized in three batches from 

14-7-08 to 27-7-08, 15-9-08 to 28-9-08 and from 

17-11-08 to 29-11-08. 

12.1.4 Training under DRUM 

Programme 

Officers were deputed to attend training 

programmes like Customer Satisfaction, 

Communication and Outreach; Electrical Safety 

Procedures, Accident Prevention & Disaster 

Management; Performance Benchmarking & 

Quality of Supply; Change Management in Power 

Distribution; GIS Supported Network Planning 

Analysis and Asset Management, etc. organized 

under the Distribution Reform, Upgrades and 

Management Programme (DRUM) – a joint 

programme developed under the Ministry of Power 

and the U.S. Aid for International Development 

(USAID), NDPL, Rohini, New Delhi. 20 Officers of 

CEA were imparted training of 100 man-days under 

DRUM programme during the year 2008-09. 

12.1.5 Information Management System 

Training in SQL for CEA 

employees 

525 employees were imparted training on 

Lotus Note, Operating System and Networking 

Administrator and Adhoc Software Development 

and Report Generation through Vayam 

Technologies Ltd.(formerly M/s. iBilt). 

12.1.6 Training of Group-D employees of 

CEA 

56 Group-D employees were imparted 

training in the fulfillment of provisions of 

the Notification of the Government on the 

recommendation of the Sixth Pay Commission. 

Each employee was imparted a training of two 

hours daily for 15 Days i.e. for 30 hrs. 

12.1.7 Training Programme on Power Plant 

Construction & Operation 

Two days workshop on “Power Plant 

Construction & Operation” by BHEL was held 

from 15.1.09 to 16.1.09 at CEA headquarter. 

12.1.8 Programme in Office Management, 

Health, Yoga etc. 

The following programmes were organized 

through various organizations to enhance the 

managerial and inter-personnel skills and for 

awareness about good health: 

(i) Inner Engineering by Isha Foundation, 

Coimbatore 

(ii) Record Management by Shri K.C. Ghosh, 

Retd. Dy. Secretary, Govt. of India 


133


(iii) Acupressure Therapy and Art of Good Living 

by Sai Institute of Learning, Dehradun. 

12.2 Foreign Training Programmes for 

Power Sector Personnel 

Foreign training programmes/ study tours 

were planned, processed and conducted during 

the year 2008-09 for CEA engineers, who 

were deputed abroad for Project Consultancy, 

International Conferences/ Seminars/ Workshops 

and Technology Transfer. The details regarding 

visits of officers who were deputed to foreign 

countries during the year 2008-09 are given in 

Annexure- 12A. 

12.3 Training Under Apprentice Act, 1961 

One Degree (Engg.), one Diploma 

(Engg.), 5 ITI qualified D/men and 35 

vocational apprentices have undergone training 

in CEA under the Apprentice Act, 1961 during 

the year 2008-09. 

12.4 Recognition of Training Institutes 

For ensuring the development of the 

training infrastructure in the Power Sector and 

the implementation of statutory requirements 

of training etc. as per Sub Rule 2(A) & 2(B) of 

Rule 3 of IE Rules 1956, the Power Training 

Institutes/Centers of various SEBs/Utilities are 

visited by CEA officers for giving recognition to 

them. The following 23 training institutes/centers 

were visited and accorded recognition/renewal of 

recognition during the year 2008-09: 

S.No. 

Name of the Institute 

1. Employee Development Centre, Farakka STPS of NTPC Ltd. 

2. Hydro Training Centre, Tanakpur HEP of NHPC Ltd. 

3. Centre for Power Sector Development, Yashada, Mahatransco 

4. National Power Training Institute(WR) of NPTI, Nagpur 

5. Employee Development Centre, NTPC, Ambedkarnagar 

6. Wanakbori Training Institute of GETRI, Gujarat 

7. Main Training Centre of Tata Power Co., Mumbai 

8. Plant Training Centre of Tata Power Co., Maharashtra 

9. Plant Training Centre of Tata Power Co., Mumbai 

10. O&M Training Centre, Salal HEP of NHPC Ltd. 

11. Electricity Training Institute of UPPCL, Lucknow 

12. Training Centre Chamera Power Station I of NHPC Ltd. 

13. Power Training Centre at Chandka, OPTCL Ltd. Orissa 

14. Thermal Training Institute, Guru Gobind Singh Super Thermal Power Stn. , PSEB, Ropar 

15. Power Station Trg. Centre, NLC, Neyveli, Tamil Nadu 

16. OHPC Training Centre, OHPC , Bhubaneshwar, Orissa 

17. Versova Technical Training Centre of Reliance Infrastructure Ltd., Mumbai. 

18. Employee Development Centre of PGCIL at Itarsi, M.P. 

19. Transmission & Distribution Training Centre of GETRI, Vadodra, Gujarat 

20. Reliance Energy Management Institute of Reliance Infrastructure at Mumbai 

21. Power Plant Simulator Training Centre at Bakreswar TPS of WBPDCL 

22. Employee Development Centre of Tanda STPS of NTPC Ltd. 

23. Koradi Training Centre, Koradi TPS, Mahagenco, Nagpur 



12.5 “Adoption of ITI” Scheme 

Central Electricity Authority and the 

Ministry of Power organized an International 

Conclave on “Key Inputs for Accelerated 

Development of Power Sector during 11 th Plan 

and beyond” on 4 th & 5 th July,2007 wherein 

Utilities, State Governments, Central & State 

Regulators, Commission and other organizations 

participated. In the wake of the International 

Conclave, the ‘Adoption of ITI' Scheme was 

launched by MoP & CEA and the CPSUs were 

advised to adopt one or more ITIs at places 

of choice near the project sites to build up the 

required manpower. 

9 Central Power Sector Utilities have 

adopted/are adopting 51 ITIs near their project 

sites to upgrade them so as to turn them into 

Centres of Excellence to provide quality 

manpower for the Power Sector. CEA has been 

facilitating the process of adoption of ITIs and 

monitoring the progress of adoption. 

12.6 Recreation and Sports Club 

The Recreation Club of CEA has been a major 

source of inspiration for the employees of CEA 

for the development of extra curricular activities. 

This is achieved by way of conducting indoor and 

outdoor games every year. The Recreation Club 

also takes part in both indoor and outdoor Inter- 

Ministry/Inter-CPSU Tournaments. 

During 2008-09, the CEA sports teams 

participated in the Inter-CPSU/Inter-Ministry 

Tournament, under the following events:- 

I. Athletic 

Sh. Dinesh Rawat is an outstanding athlete of 

CEA. During 2008-09, he continued to bring 

laurels to CEA and the country in various sports 

events. He has also won 3 Gold Medals in the 30 th 

During October 2007, the Ministry of 

Power organized a Seminar on Requirement 

of Highly Qualified Manpower for the Power 

Sector. In the follow up to the decisions taken in 

the Seminar, the Ministry of Power constituted 

five Task Forces on Integration of ITIs to build up 

a base of qualified manpower. The Task Forces 

have submitted their reports. Task Force IV inter 

alia included ‘Establishing a Power Job Portal’. 

In accordance with the recommendations of the 

Task Force, a web portal exclusively for powerrelated 

jobs has been established to work as an 

interface between job seekers and employers. 

12. Central Public Sector Undertakings/ Govt. 

bodies in the Power Sector have registered 

themselves on the website and are publicizing 

their vacancies on the web site. 


135


Masters National Athletics Championship held at 

Hissar, Haryana, from 19 th to 22 nd March, 2009 in 

100 m, 200 m and 400 m events. 

Sh. Rawat has won 5 Gold Medals in the 15 th 

Asian Masters Athletic Championship held at 

Changmai, Thailand from 1 st to 5 th December, 

2008. He won the highest number of Gold 

Medals (by any individual athlete) in the 

Championship. He won medals in 100 m, 200 m, 

400 m, 4 × 100 m and 4 × 400 m events. 

Recently, he has also won one Gold Medal in the 

Inter-Ministry Athletic Championship held at 

Vinay Marg Ground, New Delhi. 

He is also coaching the Delhi State Athletic Team for 

the forthcoming Commonwealth Games, 2010. 

II. 

Carrom 

Men’s Carrom Team of CEA has won Gold Medal 

in the Inter-CPSU Carrom Tournament organized 

by REC at New Delhi. Sh. Sumeet Kumar stood 

Runners-up in Men’s Single. Sh. Chandrashekhar 

and Sh. Sumit Kumar were the Winners in the 

Open Doubles. 

Women’s Carrom Team has also won Silver 

Trophy in the same event. The CEA sports teams 

have also participated in Kabaddi and Volleyball 

Tournaments organized by CPSUs. 

***** 



Sl. 

No 

Annexure-2A 

(Item 2.9.1) 

Status of Projects under National Perspective Plan 

on R&D for Power Sector 

Title of the Project 

1. Development of Silt 

Erosion Resistant 

Material for 

Turbines of Hydro 

generators 

2. 

(a) 

2. 

(b) 

National Effort to 

develop Technology 

for Custom 

Power Devices 

(STATCOM) 

National Effort to 

develop Technology 

for Custom 

Power Devices 

(STATCOM) 

3. Development of 

Superconducting 

Transformers 

4 To develop a 

prototype of 132kV 

Optical Current 

Transformer for 

use in the 132kV 

system 

Project 

Implementing 

organization 

NML 

Jamshedpur 

4 x 500 kVAr 

by C-DAC 

for IT-Park. 

2.5 MVAr for 

Steel Plant 

by BHEL 

Project Funding 

Sources 

(Rs. Lakh) 

NHPC : 100.00 

SJVNL : 50.00 

MoP : 149.79 

Total : 299.79 

CDAC : 125.0 

MoP : 125.0 

BHEL : 192.5 

EMCO MoP : 100.0 

ERDA 

Funds Released to 

lead agencies 

(Rs. Lakh) 

NHPC share : 45.0 

SJVNL share : 20.0 

MoP share : 71.0 

Total : 136.0 

MoP Share 120.0 

MoP : 192.5 MoP share: 57.75 

EMCO : 100.0 

Total : 200.0 

PGCIL : 19.0 

MoP - 

Total Rs. 19.0 



Status of the project 

(1/1) 

● laboratory evaluation of damage 

mechanisms in the underwater 

components on the samples of 

under water parts from Salal and 

NJHPS projects is in progress. 

● Investigation of 13Cr-4Ni with 

200µ m silt particle of samples 

are in progress on wear Erosion 

set-up as per ASTM G-32. 

● The panel fabrication drawings 

for all the 500kVA units 

completed. 

● Design and tested SMP, power 

and control module of the Lab 

Proto unit. 

● Inverter mode as well as 

STATCOM mode operation 

completed on lab proto model. 

● The controller board has been 

fabricated. 

● Modeling of arc furnace for flicker 

generation has been completed. 

● Simulation studies on 3-level 

NPC Inverter based STATCOM 

for power factor controls have 

been completed. 

● Design of power circuits, control 

circuits is in progress. 

● Development of DSP based 

control S/W is in progress. 

Purchase orders released for 

procuring Superconducting tape for 

LV & HV windings, Cryocooler, 

Vaccum Pump & other accessories, 

temperature Sensors & Monitors, 

Liquid Nitrogen, and Liquid 

Nitrogen Level Sensor. 

● Studies concerning various 

optical components and required 

methodologies are completed. 

● Demonstration of the Faraday 

principle using quartz rod and 

laser source is completed. 

● Initial investigation of 

compatibility of the laser source 

and detector has been completed. 


137


Awardees for The Year 2007-08 

Annexure-2B 

(Item 2.13.3) 

Sl.No. Awarded Station/ Project/ Company Organisation Category 

A.GOLD SHIELD WINNERS 

1. Talcher STPS (3000 MW) NTPC Thermal Power Station Performance 

2. Baspa-II (3x100 MW) JPHPCL Hydro Power Station Performance 

3. Omkareswar Unit-1 (65 MW) NHDC Early completion of Hydro Power 

Project. 

4. West Bengal State Electricity 

WBSETCL Transmission System Availability 

Transmission Co. Ltd. 

5. PowerGrid North Eastern Region POWERGRID Transmission System Availability 

6. 220 kV Rajpar AC Sub-station of 

GETCO 

GETCO 

Early completion of Power 

Transmission Project 

7. APEPDCL, Andhra Pradesh APEPDCL Distribution Company Performance 

Award 

8. M/s Mandal Mahila Samakhya, Kurupam 

of APEPDCL Discom 

B. SILVER SHIELD WINNERS 

APEPDCL 

Rural Distribution Franchisee 

Performance Award 

1. Korba STPS (2100 MW) NTPC Thermal Power Station Performance 

2. Ramagundam STPS (2600 MW) NTPC Thermal Power Station Performance 

3. Bhira and Bhira Pump Storage Scheme Tata Power Hydro Power Station Performance 

(6x25 + 1x150 MW) 

Co.Ltd. 

4. PowerGrid Western Region POWERGRID Transmission System Availability 

5. 400 kV Gooti-Raichur D/C (Quad) POWERGRID Early completion of Power 

Transmission Project 

6. BEST, Maharashtra BEST Distribution Company Performance 

Award 

7. M/s Amit Kumar of NPCL of UP Discom NPCL Rural Distribution Franchisee 


C. BRONZE SHIELD WINNERS 

1. Dadri TPS (840 MW) NTPC Thermal Power Station Performance 

2. Rihand STPS (2000 MW) NTPC Thermal Power Station Performance 

3. Torangallu TPS (260 MW) JSW Energy Co. Thermal Power Station Performance 

Karnataka 

4. Gerusupa (4x60 MW) KPCL Hydro Power Station Performance 

Award 

5 New Delhi Power Ltd. NDPL Distribution Company Performance 

Award 

6. M/s Mandal Mahila Samakhya, Paderu 

of APEPDCL Discom 

APEPDCL Rural Distribution Franchisee 


Note: No thermal power project qualified for Award for Early Completion. Similarly, no nuclear power station qualified 

for meritorious performance award during the year 2007-08. 

(1/1) 



Sl. 

No 

Name of Block 

Annexure-2C 

(Item No.2.14.18) 

Coal Blocks allotted to Power Utilities 

Total 

reserve 

MT 

Date of 

Allot ment 

Name of 

Utility 

End use Project. 

End use 

TPS 

Comm. 

Schedule 

Coal Mining 

and start of coal 

production 

Schedule 

period/Actual / 

Anticipated 

1 2 3 4 5 6 7 8 

A Central Sector 

1. Pakri Baradih 

(Jharkhand) 

1600 11.10.04 NTPC Basket of NTPC 

Projects 

Existing 15.01.2009 / 

01/10 

2. Kerandari 

(Jharkhand) 

3. Chatti Bariatu 

(Jharkhand) 

4. Dulanga 

(Orissa) 

5. Talaipalli 

(Chhatisgarh) 

Brahmini & 

6. Chichropatsimal 

(1900+356) (Orissa) 

7. Barjora (N) 

(WB) 

8. Khagra Joydev 

(WB) 

9. Kasta (E) 

(WB) 

229 25.01.06 NTPC BarhSt-II (2x800 

MW) & Tanda Exp. 

243 25.01.06 NTPC Barh St-II (2x880 

MW) & Tanda Exp. 

260 25.01.06 NTPC Darlipalli, (4x800 

=3200MW) 

2010-11 25.05.2010 / 

05/11 

2010-11 03.08.09/ 08/10 

- 15.08.2011/ 

08/11 

965 25.01.06 NTPC Lara, (4000 MW) 2011-12 02/12 / 02/12 

2256 25.01.06 NTPC & 

CIL JV 

Kahalgaon Exp. & 

Farakka Exp. 

85.49 DVC Mejia U-7&8 

(2x250 MW) 

196.15 DVC Mejia U-7&8 

(2x250 MW) 

105 DVC Mejia U-7&8 

(2x250 MW) 

- - 

2009-10 -/Mar.,07- 

Jun.,08/--- 

2009-10 Sep.,2008/ 

April, 09. 

2009-10 

10. Saharpur Jamarpani 600 25.07.07 DVC Durgapur Steel 2009-10 

TPP (2x500 MW) 

& Koderma TPP 

(2x500 MW) 

11. Gondulpara Ph-I: 

& Ph-II: 

140 13.01.06 JV of DVC 

& TVNL 

Details not available - -/April, 2010 

12. Chhatrasal 150 26.10.06 Sasan (PFC) 

SVUMPP 

Sasan UMPP (4000 

MW) 

- 

(A) Total Reserve 

Central Sector (Million 

MT) 

B State Sector 

1. Pathuria & Gidhmuri 

(269.25+80.27) 

( Chhatisgarh) 

2. Parsa 

( Chhatisgarh) 

6829.64 

349.52 23.09.04 CSEB Bhaiyathan TPS 

(3x500 MW) 

150 02.08.06 CSEB Marwa TPS (2x500 

MW) 

2012-13 Mar.,09/ 

Sep.,09 

2012-13 -/ Feb.,2012 


139


3. Tara (Chhatisgarh) 255 13.08.03 CMDCL Prem Nagar TPS 

JV of IFFCO-CSEB 

(2x660 MW) 

4. Pachwara (N) 

(Jharkhand) 

5. Bajora, 

Gangaramchak 

(Kasta)&Bhadulla- 

Gangaramchak 

(8+14) (WB) 

6. Barang-I (1 to 4) 

Manoradeep & 

Kiloni (67.57+ 

49.82+39.51) 

(Maharastra) 

(2/3) 

- March.,08/ Oct- 

08 

392.84 26.04.05 WBPDCL Sagardigi (2x300 

MW), Bakereshwar 

(2x210 MW), 

Santaldih(1x250 

MW) 

2008-09 -/2011-12 

22 23.06.03 WBPDCL ---Do----- 2008-09 22.12.06/2008-09 

152.52 10.11.03 KPCL Ballary -1 (500 

MW) + Raichur-8( 

250 MW) 

2007-08 -/May, 08 

7. Badam (Jharkhand) 144.63 03.11.03 TVN Ltd Tenughat st-III 2008-09 -----/06/09 

8. Rajbar (R&D) 

385 TVNL - -/April,2012 

(Jharkhand) 

9. Pachwara Central 

(Jharkhand) 

2007-08 -/ March, 06 (A) 

10. Machhakatta & 

Mahanadi 

(B)Total Reserve State 

Sector(Million MT) 

(C) Private Sector 

1. Tokisud (N) 

sub captive coal 

Mine, Hazaribagh 

(Jharkhand) 

2. Gare-Palma IV 2 &3 

(Chhatisgarh) 

3. Mandakini “A” 

(Talcher Coal Field, 

Orissa) 

(‘C) Total Reserve 

Private Sector (Million 

MT) 

562 26.12.01 PSEB 

(PANEM 

Coal Mines 

Ltd.) 

1200 06.02.06 Mahaguj 

Collieries 

Ltd. JV of 

MSPGCL & 

GSECL 

3616.51 

92.3 07.01.02 GVK 

Power Ltd. 

(Goidwal 

Sahib) 

246 01.07.98 Jindal Power 

Ltd. 

290.52 09.01.2008 JV of M/s 

Jindal Photo 

Ltd, M/s 

Monnet Ispat 

& Energy 

Ltd & M/s 

Tata Power 

Co. Ltd. 

628.82 

Lehra Mohabat 

GHTP ST II (2x250 

MW) 

Koradi (3x500 MW) 

& Chandrapura 

(1x500 MW) Ukai 

(1x500 MW) 

Goidwal Sahib TPS 

(2x270 MW) 

O.P. Jindal STPS 

(4x250 MW) 

Jindal Photo Ltd – 

2x600 MW ( Orissa) 

2012-13 Nov.,11/ Aug.,11 

2011-12 07.01.06/ 

01.01.09 

2007-08 Sep.,06/15.06.07 

(A)(production 

started) 

- July-11 



(D) CAPTIVE POWER PLANTS 

1. Talabira - II &III 

( II-152.3) 

2. Utkal-D 

(Orissa) 

3. Utkal-C 

(Orissa) 

4. Gare Palme-IV/7 

(Chhatisgarh) 

554 10.11.05 JV.of NLC 

& M/s 

Hindalco 

& M/s 

Mahanadi 

coal fields 

Ltd. 

153.31 19.12.03 Orissa 

Mining 

Corp. 

208.77 29.05.98 Utkal Coal 

Ltd. 

156 25.04.2000 Raipur Alloy 

& Steel Ltd. 

Aditya Aluminium 

CPP -700 MW 

2010-11 05/09 

Captive TPS - Dec.,07 

Chaudwar (108 

MW), UPLTPP Ph-I 

( 120 MW), Ph-II 

(240 MW) 

Captive TPS (18 

MW) 

(3/3) 

2008-09 Oct.,07- April,08/ 

2007-08 

- June, 05/ 

27.02.08 

5. Jamkhani 

(Orissa) 

6. Utkal -E 

(Orissa) 

110 03.11.03 Bhushan Ltd Bhushan Ltd (40+60 

MW) 

194 27.08.04 NALCO Captive TPS (2x120 

MW) 

7. Mahan 144.2 12.04.06 HINDALCO 

& ESSAR 

Ltd. 

2x600MW TPP of 

ESSAR & 750 MW 

of HINDALCO 

Existing 2008-09/ 

30.06.07 

2009-10 01.04.09/31.10.09 

- 

11.10.09/ 

10/09 

8. Tubed 189 01.08.07 Hindalco- 

Tata Power 

750 MW captive 

TPP at Latehar 

9. Talabira -I 22.5 25.02.94 Hindalco Captive TPP(3x100 

MW) 

(‘D) Total Reserve 

Captive Power Sector 1731.78 

(Million MT) 

Grand Total (A+B+C) 12806.8 

2011-12 

Existing 

-/ 29.10.03(A) 


141


Annexure-3A 

(Item No.3.3) 

Details of Inter-Regional Transmission – Existing and 

Planned for 11 th Plan: 

Name of System 

At the 

end of 10 th 

Plan i.e. 

31.03.2007 

Additions 

during 11 th 

Plan upto 

20.03.09 

Existing as on 

31.03.2009 

Balance 

program 

for 11 th 

Plan 

At the 

end of 11 th 

Plan i.e. 

31.03.2012 

(a) (b) (c=a+b) (d) (e=c+d) 

ER – SR : 

Gazuwaka HVDC back to back 1000 1000 - 1000 

Balimela-Upper Sileru 220kV S/C 130 130 - 130 

Talcher-Kolar HVDC Bipole 2000 2000 - 2000 

Upgradation of Talcher–Kolar HVDC 

500 500 - 500 

bipole 

ER-SR total 3130 500 3630 0 3630 

ER –NR : 

Muzaffarpur - Gorakhpur 400kV D/C 2000 2000 - 2000 

(Quad Moose) with TCSC 

Dehri-Sahupuri 220kV S/C 130 130 - 130 

Patna-Balia 400kV D/C quad 800 800 1600 - 1600 

Biharshariff-Balia 400kV D/C quad 1600 1600 - 1600 

Barh-Balia 400kV D/C quad 1600 1600 

Sasaram–Fatehpur 765kV S/C line-1 2100 2100 

Gaya–Balia 765kV S/C 2100 2100 

Sasaram: 500 500 1000 - 1000 

(i) HVDC back to back 

(ii) Bypassing of HVDC back-toback to establish Sasaram-Allahabad/Varanasi 400kV D/C line 

ER-NR total 3430 2900 6330 5800 12130 

ER - WR : 

Rourkela-Raipur 400kV D/C 1000 1000 - 1000 

TCSC on Rourkela-Raipur 400kV 400 400 - 400 

D/C 

Budhipara-Korba220kV D/C+S/C 390 390 - 390 

Ranchi-Sipat 400kV D/C (40% S/C) 1200 1200 - 1200 

Ranchi-Rourkela-Raipur 400kV D/C 

1400 1400 

with fixed series capacitor, TCSC in 

parallel line 

Ranchi – Sipat Pooling Point 765kV 

2100 2100 

S/C 

ER-WR total 1790 1200 2990 3500 6490 

ER - NER : 

Birpara-Salakati 220kV D/C 260 260 - 260 

Malda-Bongaigaon 400kV D/C 1000 1000 - 1000 

(1/2) 



Bongaigaon-Siliguri 400kV D/C 

1600 1600 

Quad 

ER-NER total 1260 0 1260 1600 2860 

NR - WR : 

Vindhychal HVDC back to back 500 500 - 500 

Auria-Malanpur 220kV D/C 260 260 - 260 

Kota-Ujjain 220kV D/C 260 260 - 260 

Agra-Gwalior 765kV S/C line-1 1100 1100 - 1100 

400kV op. 

Agra-Gwalior 765kV S/C line-2 

1100 1100 - 1100 

400kV op. 

Kankroli-Zerda 400kV D/C 1000 1000 

NR-WR total 2120 1100 3220 1000 4220 

WR-SR : 

Chandrapur HVDC back to back 1000 1000 - 1000 

Barsur–L.Sileru 200kV HVDC mono @ 200 200 - 200 

pole 

Kolhapur-Belgaum 220kV D/C 260 260 - 260 

Ponda – Nagajhari 220kV D/C 260 260 - 260 

Narendra/Kolhapur HVDC back-to 

1000 1000 

back with Narendra-Kolhapur 400kV 

D/C line 

WR-SR total 1720 0 1720 1000 2720 

NER/ER-NR/WR : 

Biswanath Chariyali–Siliguri–Agra 

3000 3000 

±800kV HVDC bi-pole line of 

6000MW capacity with 3000MW 

terminal modules at Bishwanath 

Chariyali and Agra 

3000MW terminal modules at 

3000 3000 

Siliguri and Agra (2 nd module) on 

Biswanath Chariyali–Siliguri-Agra ± 

800kV HVDC bi-pole line 

NER/ER-NR/WR total 0 0 0 6000 6000 

TOTAL ALL INDIA (200kV & 13450 5700 19150 18900 38050 

above) 

132kV/110kV Inter-Regional links $ 600 0 600 0 600 

4xD/C + 4XS/C = 12 ckts 

TOTAL ALL INDIA 

(110/132kV & above) 

14050 5700 19750 18900 38650 

Note: 

@ - 200 MW HVDC Monopole is currently not in operation. 

$ - 132/110kV lines are operated in radial mode from time to time. 

(2/2) 


143


UTTARAKHAND 

Annexure- 3B 

144 

“Children are our most valuable natural resource.”


Annexure- 3B 

Satluj 


145


Annexure- 3B 

146 

“A person without a sense of humor is like a wagon without springs-jolted by every pebble in the road.”


Annexure- 3B 


147


Annexure- 3B 

148 

“Failing to plan is planning to fail.”


Annexure- 3B 


149


Annexure- 3B 

150 



Annexure- 3B 


151


ISSUES PERTAINING TO TRANSMISSION SYSTEM PLANNING 

DISCUSSED / RESOLVED DURING 2008-09 

A. Northern Region 

Annexure-3C 

(Item No.3.7) 

1. 25th Meeting of the Standing Committee on Power System Planning in Northern Region 

held on July 17, 2008 at NRPC New Delhi. 

‣ Sharing of Charges for transmission system associated with Sasan and Mundra UMPPs 

‣ Evacuation of power from Jhajjar TPS (1500 MW) 

‣ Transmission system associated with Dadri II TPS (2x490 MW) 

‣ Transmission system associated with Bawana CCGT - connectivity of the Bawana CCGT with grid 

‣ Evacuation system from Kotlibhel IA (195 MW), Kotlibhel 1B (320 MW) and Kotlbhel -2 

(530 MW) HEPs in Uttaranchal 

‣ Evacaution system from Chamera III (230 MW) and Budhil HEP 

‣ Narendra - Kohlapur HVDC back-to-back scheme : NR constituents generally agreed for the 

proposal of sharing 25% of the transmission charges subject to approval by NRPC 

‣ 765 kV ring around Delhi. 

2. 26th Meeting of the Standing Committee on Power System Planning in Northern Region 

held on October 13, 2008 at Chamba, Uttarakhand. 

‣ Intra-stateTransmission System in Uttar Pradesh. 

‣ Intra-state Transmission System and Dedicated transmission lines of generators in Haryana. 

‣ Intra-stateTransmission System in Punjab 

‣ 765kV System for the Central part of Northern Grid 

‣ New Regional Schemes:- 

(1) Provision for 3 rd 400/220 kV ICT at Bhiwadi 

Haryana has proposed this to provide connectivity through LILO of 2 nd 200 kV line 

from Badshapur – Riwari of HVPNL 

(2) 2 nos. of additional 220 kV bays at Panchkula, Sonipat(PG) and Gurgaon sec-72 s/s of 

PGCIL for HVPNL 

Haryana has proposed the above additional 220kV bays in line with the decision taken 

in the 23 rd SCM to have 6 bays with first two 400/220 kV, 315 MVA ICT. The bays are 

to be utilized by HVPNL for meeting load demand of that area. 

(3) With Bhiwani 765/400kV substation 

Regional scheme of PGCIL 

(1/4) 



• Bhiwani-Jind 400kV D/C 

• Jind 400/220kV 2x315 MVA substation 

To be constructed by HVPNL at their own cost 

• Bhiwani-Rohtak 400kV D/C 

• Jind-Hissar HVPN 400kV s/s D/C 

(4) 400 kV S/S at Sohawal with 2x315 MVA ICT, to be established by LILO of both the 

circuit of Balia - Lucknow 400 kV D/C line 

UPPCL has proposed the above s/s for meeting load demand in Faizabad area. 

(5) Saharanpur 400 kV S/S with 2x315 MVA ICT to be established by LILO of both the 

ckt of Dehradun - Baghpat 400 kV quad line 

UPPCL has proposed the above s/s for meeting load demand in Saharanpur area. 

(6) Shahjahanpur 400 kV S/S with 2x315 MVA ICT to be established by LILO of both the 

ckt of Lucknow (PG) – Bareilly (PG) 400 kV D/C line 

(2/4) 

UPPCL has proposed the above s/s for meeting load demand in Shahajahanpur area. 

This regional s/s is prosed in lieu of Hapur s/s agreed earlier but not proposed under 

PGCIL now due to 765/400/220 s/s of UPPCL at Hapur. 

(7) Creation of new 220/400 kV S/S at Jaipur (South) with 2x500 MVA transformer to be 

created by LILO of Agra - Jaipur line at Jaipur 

The new substation at Jaipur would help in mitigating the heavy loading on the existing 

400 kV S/S at Jaipur 

(8) Creation of 220/400 kV 2x500 MVA S/S at Ramban by LILO of the proposed 400 kV 

line from Kishenpur to New Wangpoh - Wagoora 

The S/S would be utilized for evacuation of power from Chenab basin project in J&K 

as well as utilized for disbursal of power at 220 kV in Jammu region. 

‣ Power Evacuation from Parbati and Koldam HEP. 

‣ Power evacuation system from Sainj HEP (100 MW) by HPPGCL. 

‣ Proposal for loop in loop out of 220 kV Jullundhur - Hamirpur line near Gagret 220/132 kV 

S/S of Himachal Pradesh 

‣ Transmission system associated with Dadri II TPS (2x490 MW) 

‣ Requirement of shifting of Sasaram HVDC module 

B. Eastern Region 

‣ Transmission System Associated with the Tilaiya UMPP (4000 MW) in Jharkhand, Barh-II 

(1320 MW) & Nabinagar (1000MW) in Bihar (JV of Railways and NTPC). 


153


(3/4) 

• Generation Specific Transmission System 

• System strengthening scheme in ER 

• ATS (under the scope of Generation Developer) to Haldia (600MW), Adunik (1000MW), 

Essar(1800MW), Electrosteel (1200MW), Corporate (800MW), and CESC Dumka 

(1200MW) and Orissa IPPs Generation Projects 

‣ 400kV Transmission proposals of GRIDCO, Orissa during XI Plan Period. 

‣ Transmission works of WBSEDCL under State Sector. 

C. Western Region 

1. 28th Meeting of the Standing Committee on Power System Planning in Western Region 

held on 06.12.2008 in Maharastra at Aurangabad 

(a) Review of Progress of Schemes under construction by POWERGRID. 

(b) Transmission System for evacuation of power from Krishnapattnam UMPP (4000 MW) and 

requirements for additional transmission capacity between SR-WR 

(c) Transmission System Associated with the Tilaiya Ultra Mega Power Project (4000 MW), 

in Jharkhand, Nabinagar (1000MW) of Railways and NTPC, Barh-II (1320 MW), Rihand- 

IV (1000MW), Vindhyachal-IV (1000MW) and Mauda (1000MW) of NTPC, and IPPs in 

Jharkhand, Orissa, MP, Chattisgarh, and Maharashtra. 

(d) Proposal of MPPTCL for 220 kV Shujalpur-Badod D/C line. 

(e) Transmission System at 400kV and 765kV in Maharashtra. Proposal for: Intra-state transmission 

system of STU, Evacuation system from generating stations (MSPGCL, MAHADISCOM and 

IPPs) and Inter-regional transmission system proposed as regional schemes. 

(f) Provision of second 400 kV feed to Union Territory of Dadra and Nagar Haveli (DNH) and 

Daman& Diu 

(g) Control of high voltages in Dhule area. 

(h) Development of 400 kV network at Gwalior 

(i) Addressing high short circuit level at 400 kV Raipur substation in WR. 

2. Meetings for arriving at consensus on the issue of sharing of transmission charges of Sasan 

and Mundra UMPP and WR-SR Inter-Regional link 

(a) With WR constituents on 16.04.2008 for sharing of transmission charges of WR-SR Inter 

Regional link. 

(b) Joint meeting of members of Standing Committee on Power System Planning of WR & NR 

on 10.06.2008 at New Delhi for sharing of transmission charges of UMPPs and WR-SR Inter 

Regional link. 



(4/4) 

(c) Joint NRPC and WRPC on 22.07.2009 at New Delhi for sharing of transmission charges of 

Sasan and MundraUMPPs 

D. Southern Region 

1. 26th Meeting of the Standing Committee on Power System Planning in Southern Region 

(a) Review of Progress of Schemes under construction by POWERGRID. 

(b) Provision of forth Transformer at Ghanapur (Hyderabad) 400/220kV S/S of POWERGRID. 

(c) Bays at Hiriyur for termination of lines by KPTCL. 

(d) Transmission System for Vallur JV TPS (3x500 MW) of NTECL and Transmission System for 

North Chennai Stage-II TPS (1x600 MW) and Ennore Expansion (1x600 MW) of TNEB 

(e) Evacuation System for 4000 MW Krishnapattnam UMPP. 

(f) Regional System Strengthening Scheme with 400kV S/S at Chulliar (Palakkad) in Kerala 

(g) 400kV Bidadi Substation. 

(h) Interconnection of Kolhapur HVDC station with existing Kolhapur (POWERGRID) substation 

under SR – WR Interconnection Project. 

(i) Agenda proposed by POWERGRID regarding LTOA Issues. 

2. 27th Meeting of the Standing Committee on Power System Planning in Southern Region 

(a) Status of under construction/ Approved Schemes in Southern Region. 

(b) Inter-connection line between Vallur JV TPS and NCTPS Stage –II projects. 

(c) Transmission System for evacuation of power from Vallur JV TPS (2x500 MW+1x500 MW) 

and North Chennai Stage-II TPS (2x600 MW). 

(d) Termination of 400kV D/C quad line from Pugalur at Sholinganallur 400kV S/S. 

(e) Execution of Singarapet 400/230kV S/S by TNEB. 

(f) Transmission system for evacuation of power from Ennore TPS (1X500 MW). 

(g) Inter-link between Tirunelveli (PGCIL) and Kanarapatty(TNEB) 400kV S/S near 

Tirunelveli. 

(h) Establishing connectivity at Yelahanka 2x500 MVA 400/220kV S/S. 

(i) Establishment of 400/220kV S/S at Electronic City in Banglore. 

(j) Establishment of 400/220kV S/S at Basana Bagewadi by KPTCL. 

(k) Transmission System for Tadri UMPP. 

(l) Transmission system for evacuation of power from Kothagudam TPS (1X500 MW) in Andhra 

Pradesh. 

(m) Evacuation system for Bhoopalapally Stage-I&II (1x500+1x600 MW) in AP. 

(n) 400/220kV transformer at Berhampur 400kV Sw.Stn. in Orrisa. 

(o) Transmission System for Evacuation of Power from Kudankulam APP Stage-II (2x1000MW). 

(p) LTOA applications made to CTU for Projects in Southern Region. 


155


Annexure-3D 

(Item No.3.13) 

Transmission Lines Completed During 2008-09 

Sl. Name of the transmission lines No. of ckts Executing 

Agency 

I. 765 KV LINES 

Line 

length 

(CKM) 

Stringing 

during 2008- 

09 (CKM) 

(1/6) 

Month of 

Completion 

1 Sipat - Seoni line-II S/C POWERGRID 354 0 Apr.’08 

2 Agra - Gwalior 2nd S/C (initially S/C POWERGRID 128 99 Mar-09 

to be operated at 400KV) 

3 Seoni - Wardha line (to be 

S/C POWERGRID 269 243 Mar-09 

operated at 400KV) 

TOTAL (CS) 751 564 

TOTAL (SS) 0 0 

TOTAL (ALL INDIA) 751 564 

II. ± 500 kV HVDC LINES 

TOTAL (CS) 0 1180 

TOTAL (ALL INDIA) 0 1180 

III. 400 KV LINES 

1 LILO of both ckt of Maduri (PG) 

-Trivendrum (PG) at Tirunelveli 

D/C POWERGRID 213 0 Apr-08 

2 Bareilly - Mordadabad S/C POWERGRID 91 0 May-08 

3 LILO of existing Kolar- 

D/C POWERGRID 31 6 May-08 

Sriperumbadur at Melakottaiyur 

S/Stn. 

4 Teesta-V - Siliguri (Ckt-II ) S/C POWERGRID 113 1 May-08 

5 Sipat - Raipur D/C POWERGRID 298 18 Jul-08 

6 RAPP 5&6 - Kankroli D/C POWERGRID 397 0 Sep-08 

7 Kota - Merta D/C POWERGRID 512 427 Jan-09 

8 Ranchi-Sipat line D/C POWERGRID 816 110 Jan-09 

9 RAPP 5&6 - Kota D/C POWERGRID 75 73 Mar-09 

10 LILO of Hissar - Jaipur at 

D/C POWERGRID 156 126 Mar-09 

Bhiwadi 

11 LILO of Rishikesh - 

D/C POWERGRID 3 3 Mar-09 

Muzaffarnagar at Roorkee 

12 Wardha - Akola D/C POWERGRID 324 224 Mar-09 

13 Pugalur - Madurai D/C POWERGRID 246 66 Mar-09 

Total CKM OF 400 kV LINES 

(CS) 

5120 



1 LILO of Korba-Sipat at 

D/C Chhattisgarh 62 10 Apr-08 

Amarkantak 

2 JTPS-Raipur D/C Chhattisgarh 516 134 May-08 

3 NSPCL-Raipur D/C Chhattisgarh 28 18 Mar-09 

4 Ramagundam(NTPC)-Ditchpally S/C Andhra 171 0 May-08 

Pradesh 

5 LILO of Ramagundam -Ghanapur D/C Andhra 

21 21 Aug-08 

at Gajwel 

Pradesh 

6 Ratangarh-Merta S/C Rajasthan 181 0 May-08 

7 Chhabra-Dahra (Kota) D/C Rajasthan 261 261 Mar-09 

8 LILO of RTPS-Guttur at BTPS D/C Karnataka 2 2 Jun-08 

9 LILO of Birsinghpur - Damoh D/C Madya Pradesh 26 6 Aug-08 

D/C at Damoh 

10 Interconnector of Birsinghpur- 

Katni-Damoh at Birsinghpur 

D/C Madya Pradesh 1 1 Aug-08 

11 Diversion of Birsinghpur-Katni- D/C Madya Pradesh 2 2 Aug-08 

Damoh at Katni 

12 LILO of Farakka-Subhashgram at D/C West Bengal 13 1 Aug-08 

Sagardighi 

13 Kishenpur-Baglihar (Ist ckt) S/C Jammu& 68 0 Oct-08 

Kashmir 

TOTAL CKM OF 400 kV 

1707 

LINES (SS) 


6827 

LINES (ALL INDIA) 

IV. 220 KV LINES 

1 Vapi (PG) - Magarwada line D/C&M/C POWERGRID 31 2 Apr-08 

2 Vapi (PG) - Kharadpada (DNH) D/C POWERGRID 34 16 Jun-08 

3 Kabul-Pul-e-Khumri 

D/C POWERGRID 404 136 Feb-09 

(Afghanistan) 

4 LILO of 1 ckt. Of Tanakpur- D/C POWERGRID 44 37 

Bareilly at Sitarganj 


241 

(CS) 

1 LILO of Pugalur-Checkanoorani D/C Tamil Nadu 32 0 Apr-08 

at Renganathapuram 

2 Ponnapuram- Palladam SC on DC Tamil Nadu 32 32 Jun-08 

3 LILO of S P Koil- Tharamani II at D/C Tamil Nadu 14 2 Jul-08 

Kalivanthapattu 400kV S/S 

4 Kayathar - Checkkanoorani 400 D/C Tamil Nadu 244 234 Jul-08 

kV S/S 

5 LILO of Sriperumbadur -S P Koil 

at Oragadom S/S 

D/C Tamil Nadu 18 18 Aug-08 

(2/6) 


157


6 LILO of S P Koil- Tharamani at D/C Tamil Nadu 5 5 Aug-08 

Veerapuram 

7 LILO of Pugalur -Myvadi at D/C Tamil Nadu 15 15 Oct-08 

proposed Pugalur 400kV S/S 

8 Alamathy S/S - Manali D/C Tamil Nadu 47 3 Oct-08 

9 LILO of Neyveli TS-II-Neyveli D/C Tamil Nadu 22.5 22.5 Jan-09 

Zero Unit at Cuddalore 

10 Sriperumbudur 400 kV S/S-Nokia D/C Tamil Nadu 11 4 Jan-09 

11 LILO of both ckts of Bhopal- 2xD/C Madya Pradesh 2 2 Apr-08 

Itarsi at Itarsi 

12 LILO of 1st Ckt of Itarsi-Bhopal D/C Madya Pradesh 12 12 Jun-08 

at Mandideep 

13 Pitampur-Raigarh (2nd) Ckt S/C Madya Pradesh 69 58 Jun-08 

14 LILO of Barwaha-Nepanagar 

(Khandwa) at Omkareshwar 

2xD/C Madya Pradesh 91 11 Jul-08 

15 LILO of both circuits of 

2xD/C Madya Pradesh 92 82 Aug-08 

Pitampur-Raigarh D/C at 

Rajgarh(PG) 

16 LILO of Birsinghpur-Satna at D/C Madya Pradesh 90 58 Sep-08 

Amarkantak (Chachai) 

17 LILO of Birsinghpur-Rewa for D/C Madya Pradesh 118 94 Nov-08 

Sidhi 

18 LILO of 1st Ckt Damoh- 

D/C Madya Pradesh 2 0 Dec-08 

Tikamgarh at Damoh(400 kV) 

19 LILO of 2nd Ckt of Damoh - D/C Madya Pradesh 10 10 Dec-08 

Bina D/C at Sagar 

20 LILO of both Ckt of Ujjain- Kota D/C Madya Pradesh 15 15 Dec-08 

at Badod 

21 Shivpuri-Sabalgarh D/C Madya Pradesh 200 195 Mar-09 

22 Akhakhol-Kim D/C Gujarat 8 0 Apr-08 

23 Bardoli-Chikali D/C Gujarat 96 0 Oct-08 

24 LILO of one Ckt of Anjar - 

D/C Gujarat 5 1 Nov-08 

Panadhro at Kukma 

25 Mundra (Adani) -Nani khakher D/C Gujarat 33 33 Dec-08 

26 NSPCL-Gurur (CSEB) S/C Chhattisgarh 20 20 Apr-08 

27 JTPS-Raigarh D/C Chhattisgarh 108 32 Feb-09 

28 NSPCL-BSP MSDS-6 D/C Chhattisgarh 8 8 Mar-09 

29 LILO from Shimoga- Mysore at D/C Karnataka 23 23 May-08 

Huygonahalli (K R Pet) 

30 LILO of SMG- Mysore at 

D/C Karnataka 33 8 Aug-08 

Kadavinakote 

31 Hoody - HAL D/C Karnataka 6 6 Oct-08 

(3/6) 



32 Khemar- Puttur(Guruvanyankere- D/C Karnataka 56 41 Jan-09 

Puttur part line) 

33 LILO of Mahalingpur- Kudachi at D/C Karnataka 48 48 Jan-09 

Athani 

34 LILO of Basavanabagevadi-Indi D/C Karnataka 12 12 Jan-09 

at Bijapur 

35 LILO of Peenya- Somanahalli at D/C Karnataka 0.5 0.5 Jan-09 

Vrishabhavathi S/S 

36 LILO of B Bagewadi- Indi line at D/C Karnataka 11.0 11.0 Feb-09 

Bijapur 

37 LILO Bhilwara-Kankroli at S/C Rajasthan 9.5 0 May-08 

Kankroli(PG) 

38 LILO of Chhabra-Baran-Dahra at D/C Rajasthan 2 2 Jul-08 

Kawai 

39 Opening of one ckt of Heerapura- S/C Rajasthan 59 0 Jul-08 

Bassi line and connecting 

Sanganer & Phulera 

40 LILO of Giral -Barmer ckt 1 at D/C Rajasthan 5 5 Aug-08 

RAJ West LTPS 

41 LILO Heerapura-Kukas at VKIA D/C Rajasthan 2 2 Sep-08 

42 Bhiwadi(PGCIL)-Neemrana S/C Rajasthan 52 26 Oct-08 

43 LILO Bhiwadi-Neemrana at D/C Rajasthan 8 8 Oct-08 

Khushkhera 

44 LILO Alwar-Bhiwadi at 

D/C Rajasthan 5 5 Oct-08 

Khushekhera 

45 LILO of Ajmer - Phulera at D/C Rajasthan 0.2 0.2 Oct-08 

Kishangarh 

46 Barsinghsar -Khinvsar S/C Rajasthan 98 98 Dec-08 

47 Dhorimanna-Bhinmal S/C Rajasthan 92 68 Feb-09 

48 Nilokheri-Karnal S/C Haryana 19 0 Jun-08 

49 LILO one ckt of Shahbad-Pehova D/C Haryana 6 6 Nov-08 

at Durala 

50 LILO Narwana-Fatehabad & D/C Haryana 5 5 Nov-08 

Fatehabad-Sirsa at Fatehabad 

(PG) 

51 LILO of Narwana-Fatehabad at D/C Haryana 16 16 Nov-08 

Bhuna 

52 YTPP-Abdullapur D/C Haryana 56 28 Feb-09 

53 Hissar (Mayyar)-Isharwal D/C Haryana 92 70 Feb-09 

54 Kiron- Bhuna D/C Haryana 60 60 Mar-09 

(4/6) 


159


55 LILO of Gobindgarh-I - 

D/C Punjab 2 2 Jun-08 

Gobindgarh-II at Amloh Road 

Gobindgarh 

56 LILO one ckt of Lalton- Jagron at D/C Punjab 4 4 Jun-08 

Ludhiana (PG) 

57 Khasa – Amritsar (at Balachak D/C Punjab 44 34 Jul-08 

(PGCIL)) 

58 Moga (400 KV)- Jagraon D/C Punjab 1 1 Jul-08 

59 GNDTP-Muktsar (2nd ckt) S/C on D/C Punjab 53 3 Dec-08 

60 LILO of Mohali-I – Dera Bassi at D/C Punjab 1 1 Feb-09 

Mohali-II 

61 Mohali-Dera Bassi (2nd ckt S/C on D/C Punjab 29 1 Feb-09 

stringing) 

62 Moga (400 KV) - Bagha Purana D/C Punjab 20 20 Mar-09 

63 Barn-Kishenpur D/C Jammu& 75 75 Jun-08 

Kashmir 

64 LILO of Paricha-Safai at 

D/C Uttar Pradesh 5 5 Aug-08 

Bharthana 

65 Loni-Muradnagar(400 kV S/S) D/C Uttar Pradesh 27 27 Jan-09 

66 LILO of Khurja-Muradnagar at D/C Uttar Pradesh 38 21 Jan-09 

Sikandrabad 

67 LILO of Sarojininagar-Chinhat at D/C Uttar Pradesh 7 7 Jan-09 

Gomtinagar 

68 LILO of C.B.Ganj- Bareilly at D/C Uttar Pradesh 4 4 Jan-09 

Dohane 

69 Padmanavpur - Balasore D/C Orissa 44 22 Nov-08 

70 IB Thermal- Budhipadar 2nd D/C D/C Orissa 52 52 Jan-09 

71 Duburi-Paradeep D/C Orissa 226 0 Mar-09 

72 Bhimavaram- Gudivada D/C Andhra 

Pradesh 

121 49 Nov-08 

73 LILO of Mamidipally- 

Chandrayanagutta ckt-2 at HIAL 

74 LILO of 2nd ckt of Malkaram- 

Minpur at Medchal 

75 LILO of VTS- Tallapally at 

Rentachintala 

D/C 

D/C 

D/C 

Andhra 

Pradesh 

Andhra 

Pradesh 

Andhra 

Pradesh 

76 LILO of Gajuwaka- VSS at GPL D/C Andhra 

Pradesh 

77 Gajwel 400 kV S/S -Kamareddy 

S/C on D/C 

S/C 

Andhra 

Pradesh 

3 3 Dec-08 

1 1 Dec-08 

2 2 Dec-08 

6 6 Feb-09 

66 58 Mar-09 

160 “Failing to plan is planning to fail.” 

(5/6)


78 Gangapur - Valve D/C Maharashtra 13 13 Dec-08 

79 Talegaon 400 kV S/S- Urse 220 D/C Maharashtra 10 5 Jan-09 

kV S/S(1st ckt) 

80 Theur - Magarpatta(LILO of 

Theur- Phursungi at Magarpatta) 

D/C Maharashtra 25 25 Mar-09 

81 Hatia-Lohardagga D/C Jharkhand 122 0 Jan-09 

82 LILO of Jeerat- Lakshmikantpur D/C West Bengal 6 6 Jan-09 

at KLC 

83 LILO of Fatna- Khagaul 1st ckt at D/C Bihar 16 16 Jan-09 

Patna(PG) 

84 LILO of one ckt of Agia- 

D/C Assam 1 1 Feb-09 

Sarusajai at Boko S/S 

85 LILO of Maneri I-Rishikesh at D/C Uttarakhand 4 0 Mar-09 

Maneri II 


3930 

(SS) 


LINES (ALL INDIA) 

4171 

(6/6) 


161


Sl. 

No. 

Sub-Staions Commissioned During 2008-09 

Name of the Sub-station 

Voltage 

Ratio (kV/ 

kV) 

Executing 

Agency 

Capacity 

(MW/MVA) 

Annexure-3E 

(Item 3.13) 

Month of 

completion 

400 kV 

1 Itarsi 400/220 POWERGRID 315 Apr-08 

2 Tirunelveli ICT- II 400/220 POWERGRID 315 Apr-08 

3 Baripada 400/220 POWERGRID 315 Apr-08 

4 Fatehabad ICT- II 400/220 POWERGRID 315 Apr-08 

5 Patna ICT- II 400/220 POWERGRID 315 Apr-08 

6 Ludhiana ICT-I 400/220 POWERGRID 315 May-08 

7 Melakottaiyur ICT-I 400/220 POWERGRID 315 May-08 

8 Ludhiana ICT-II 400/220 POWERGRID 315 Jul-08 

9 Kankroli S/S ICT I & II 400/220 POWERGRID 630 Sep-08 

10 Damoh ICT- I 400/220 POWERGRID 315 Sep-08 

11 Melakottaiyur ICT-II 400/220 POWERGRID 315 Sep-08 

12 Damoh ICT - II 400/220 POWERGRID 315 Nov-08 

13 Tirunelveli ICT-I 400/220 POWERGRID 315 Nov-08 

14 Bhatapara ICT-II 400/220 POWERGRID 315 Jan-09 

15 Kota S/S 400/220 POWERGRID 630 Mar-09 

16 Roorkee S/S 400/220 POWERGRID 315 Mar-09 

17 Rajgarh S/S ( 2nd ICT) 400/220 POWERGRID 315 Mar-09 

18 Wardha 400/220 POWERGRID 315 Mar-09 

19 Udumalpet (PG)(Ext) 400/220 POWERGRID 315 Mar-09 

20 Pugalur S/S 400/220 POWERGRID 315 Mar-09 

TOTAL (Central Sector) 6930 

1 NSPCL (2x315 MVA) 400/220 Chhattisgarh 315 Apr-08 

2 Gajwel ICT -I 400/220 APTRANSCO 315 Sep-08 

3 Gajwel ICT -II 400/220 APTRANSCO 315 Mar-09 

4 Sarnath Extn.2x(160-100) 400/220 Uttar Pradesh 120 Oct-08 

TOTAL (State Sector) 1065 

TOTAL(All India) 7995 

220 kV 

1 Sitarganj 220/132 POWERGRID 100 Feb-09 

2 Barjora 220/33 DVC 100 Feb-09 

TOTAL (Central Sector) 200 

1 Renganathapuram(2x50) 230/110 Tamil Nadu 50 Apr-08 

2 Perambalur Add. Trans. 230/110 Tamil Nadu 100 May-08 

(1/4) 

162 



3 Palladam 230/110 Tamil Nadu 200 Jun-08 

4 Veerapuram 230/110 Tamil Nadu 100 Jun-08 

5 Pudhanchandi (Add. Trans) 230/110 Tamil Nadu 100 Jun-08 

6 Udayathur (Add.Trans) 230/33 Tamil Nadu 50 Jun-08 

7 Korattur (Add.Trans) 230/110 Tamil Nadu 100 Jul-08 

8 Oragadam 230/110 Tamil Nadu 100 Aug-08 

9 Manali (Add.Trans.) 230/110 Tamil Nadu 100 Aug-08 

10 Thiruvalam(Aug.)(100-80) 230/110 Tamil Nadu 20 Oct-08 

11 Udayathur (Add.Trans) 230/33 Tamil Nadu 50 Jan-09 

12 Kadapperi(Aug.)(2x100-2x80) 230/110 Tamil Nadu 40 Jan-09 

13 Amuthapuram 230/33 Tamil Nadu 50 Jan-09 

14 Balipara (Tezpur) 220/132 Assam 50 Apr-08 

15 Boko 220/132 Assam 50 Feb-09 

16 Wada 220/22 Maharashtra 50 Apr-08 

17 Pandhanpur 220/22 Maharashtra 50 Jul-08 

18 Kolshet 220/22 Maharashtra 50 Jul-08 

19 Bhugaon 220/33 Maharashtra 25 Sep-08 

20 Bhiwandi II(Kamba) 220/22 Maharashtra 50 Sep-08 

21 Kurkambh (50-25) 220/33 Maharashtra 25 Sep-08 

22 Kolshet 220/100 Maharashtra 200 Sep-08 

23 Bhigwan (Aug.) 220/33 Maharashtra 25 Oct-08 

24 Pusad 220/132 Maharashtra 100 Nov-08 

25 Malegaon II 220/32 Maharashtra 50 Nov-08 

26 Nalasopara 220/22 Maharashtra 50 Nov-08 

27 Gangapur (3x100) 220/132 Maharashtra 300 Dec-08 

28 Phursungi(2x100) 220/132 Maharashtra 200 Dec-08 

29 Wather 220/132 Maharashtra 100 Mar-09 

30 Nerul 220/33 Maharashtra 25 Mar-09 

31 Magarpatta(3x50) 220/22 Maharashtra 150 Mar-09 

32 K.R Pet(Huyoganahally) 220/66 Karnataka 60 May-08 

33 Yerandanahalli (3rd Trans.) 220/66 Karnataka 100 Jun-08 

34 Shahapur (2nd Trans) 220/110 Karnataka 100 Jun-08 

35 Allipura (Add.Trans) 220/110 Karnataka 100 Jul-08 

36 Kadavinakote(2x100) 220/66 Karnataka 200 Aug-08 

37 HAL 220/66 Karnataka 100 Oct-08 

38 Puttur 220/110 Karnataka 100 Dec-08 

39 HAL(2nd Trans.) 220/66 Karnataka 100 Jan-09 

40 Athani 220/110 Karnataka 100 Jan-09 

41 Vrishabhavaathi Valley(2x100) 220/66 Karnataka 100 Feb-09 

42 Shiralkoppa(2x100) 220/110 Karnataka 100 Feb-09 

(2/4) 


163


(3/4) 

43 Bijapur(2x100) 220/110 Karnataka 100 Feb-09 

44 Salempur (2nd ICT) 220/132 Haryana 100 May-08 

45 Nilokheri S/S (2x100 MVA) 220/132 Haryana 100 Jul-08 

46 Ballabhgarh Aug 220/132 Haryana 100 Jul-08 

47 Daultabad 2nd ICT 220/66 Haryana 100 Jul-08 

48 Durala 220/132 Haryana 100 Nov-08 

49 Jorian(Aug.) 220/66 Haryana 100 Nov-08 

50 Bhuna (2x 100 MVA) 220/132 Haryana 100 Nov-08 

51 Palli (Aug.) 220/66 Haryana 100 Nov-08 

52 Nilokheri S/S 2nd trans. 220/132 Haryana 100 Dec-08 

53 Yamunanager(Jorian) 3rd ICT 220/66 Haryana 100 Feb-09 

54 Tepla Aug 220/66 Haryana 100 Mar-09 

55 Dhuri (Aug) (2nd Trans.) 220/66 Punjab 100 Jun-08 

56 Amloh Rd Gobindgarh 220/66 Punjab 100 Jun-08 

57 Goraya(Aug.) 220/132 Punjab 100 Sep-08 

58 GNDTP,BTI Aug.(100-50) 220/66 Punjab 50 Oct-08 

59 Rajla (Aug) 220/66 Punjab 100 Dec-08 

60 GHTP Lehra Mohabat 220/66 Punjab 100 Feb-09 

61 Atrauli Extn. 2 220/132 Uttar Pradesh 100 Jun-08 

62 Agra Cant.(63-40) 220/132 Uttar Pradesh 23 Jul-08 

63 Loni 220/132 Uttar Pradesh 100 Oct-08 

64 Dohna, Bareilly 220/132 Uttar Pradesh 200 Oct-08 

65 Bharthana 220/132 Uttar Pradesh 100 Oct-08 

66 Azamgarh Aug.2x(160-100) 220/132 Uttar Pradesh 60 Oct-08 

67 Muradnagar Extn.(160-100) 220/132 Uttar Pradesh 60 Nov-08 

68 Saharanpur Extn.(160-100) 220/132 Uttar Pradesh 60 Nov-08 

69 Sikandrabad(2x100) 220/132 Uttar Pradesh 200 Jan-09 

70 Nehtaur Aug. (160-100) 220/132 Uttar Pradesh 60 Jan-09 

71 Gomti Nagar(3x60) 220/33 Uttar Pradesh 180 Jan-09 

72 Loni(2nd Trans.) 220/132 Uttar Pradesh 100 Jan-09 

73 Hardoi Road Ext. (160-100) 220/132 Uttar Pradesh 60 Jan-09 

74 Jaunpur Extn. (160-100) 220/132 Uttar Pradesh 60 Jan-09 

75 Hathras Extn. (160-100) 220/132 Uttar Pradesh 60 Jan-09 

76 Simboli Extn. (160-100) 220/132 Uttar Pradesh 60 Jan-09 

77 C.B.Ganj Extn. (3x60) 220/132 Uttar Pradesh 60 Jan-09 

78 Phoolpur Extn.(160-100) 220/132 Uttar Pradesh 60 Mar-09 

79 Kawai 220/132 Rajasthan 100 Jul-08 

80 Kishangarh (Ajmer) 220/132 Rajasthan 100 Sep-08 

81 VKIA 220/132 Rajasthan 100 Sep-08 

164 



(4/4) 

82 Neemrana 220/132 Rajasthan 100 Oct-08 

83 Khushkhera(Alwar)(1x100) 220/132 Rajasthan 100 Jan-09 

84 Beaver(Aug.) 220/132 Rajasthan 50 Mar-09 

85 Phalodi(Aug) 220/132 Rajasthan 50 Mar-09 

86 Kuchaman City(Aug.) 220/132 Rajasthan 100 Mar-09 

87 Alwar (Aug.) 220/132 Rajasthan 50 Mar-09 

88 Dahra (Aug.) 220/132 Rajasthan 100 Mar-09 

89 Kukma 220/66 Gujarat 100 Aug-08 

90 Bala (2x50) 220/11 Gujarat 100 Feb-09 

91 Dudhrej (2x25) 220/11 Gujarat 50 Feb-09 

92 Suhela (Bhatapara) 220/132 Chhattisgarh 160 Aug-08 

93 Main step down sub-station 220/132 Chhattisgarh 160 Mar-09 

(MSDS)-6 

94 Mandideep 220/132 Madhya Pradesh 160 Sep-08 

95 Sagar 220/132 Madhya Pradesh 160 Dec-08 

96 Badod 220/132 Madhya Pradesh 160 Dec-08 

97 Hoshangabad 220/132 Madhya Pradesh 160 Feb-09 

98 Sabalgarh 220/132 Madhya Pradesh 160 Mar-09 

99 Mandideep 220/132 Madhya Pradesh 100 Mar-09 

100 Damoh(Add Trans.) 220/132 Madhya Pradesh 160 Mar-09 

101 Rajgarh(Dhar)(Add.Trans) 220/132 Madhya Pradesh 160 Mar-09 

102 Barn (2x160) 220/132 Jammu& Kashmir 

160 Oct-08 

103 Manimajra (Chandigarh) 220/66 Chandigarh 100 Nov-08 

104 Rentachintala 220/132 Andhra Pradesh 100 Dec-08 

105 Gajwel (ICT-I) 220/132 Andhra Pradesh 100 Feb-09 

106 Kamareddy 220/132 Andhra Pradesh 100 Mar-09 

107 Gangavaram port 220/33 Andhra Pradesh 31.5 Mar-09 

108 Fatuah(Aug.) 220/132 Bihar 100 Jan-09 

109 KLC 220/132 West Bengal 100 Jan-09 

110 Gokarna(3rd Trans.) 220/132 West Bengal 100 Jan-09 

111 Bawana DSIDC 220/66 Delhi 100 Feb-09 

112 South of Wazirabad (4th ICT) 220/66 Delhi 100 Feb-09 

113 GT S/S (Aug)(160-100) 220/33 Delhi 60 Feb-09 

114 Barkote(ICT- II) 220/33 Orissa 20 Feb-09 

115 Paradeep(1st) 220/132 Orissa 100 Mar-09 

TOTAL (State Sector) 220 11034.5 

TOTAL (All India) 220 11234.5 


165


State / System / Region 

Power Supply Position during 2008-09 

Requirement 

Availability 

Surplus / 

Deficit (-) 

Peak 

Demand 

Annexure 4A 

(Item No. 4.2) 

Peak Met Surplus / 

Deficit (-) 

( MU ) ( MU ) ( MU ) ( % ) ( MW ) ( MW ) ( MW ) ( % ) 

Chandigarh 1,414 1,414 0 0.0 279 279 0 0.0 

Delhi 22,398 22,273 -125 -0.6 4,036 4,034 -2 0.0 

Haryana 29,085 26,625 -2,460 -8.5 5,511 4,791 -720 -13.1 

Himachal Pradesh 6,260 6,241 -19 -0.3 1,055 1,014 -41 -3.9 

Jammu & Kashmir 11,467 8,698 -2,769 -24.1 2,120 1,380 -740 -34.9 

Punjab 41,635 37,238 -4,397 -10.6 8,690 7,309 -1,381 -15.9 

Rajasthan 37,797 37,388 -409 -1.1 6,303 6,101 -202 -3.2 

Uttar Pradesh 69,207 54,309 -14,898 -21.5 10,587 8,248 -2,339 -22.1 

Uttaranchal 7,841 7,765 -76 -1.0 1,267 1,267 0 0.0 

Northern Region 227,104 201,951 -25,153 -11.1 33,034 29,504 -3,530 -10.7 

Chhattisgarh 14,866 14,475 -391 -2.6 2,887 2,830 -57 -2.0 

Gujarat 67,482 60,851 -6,631 -9.8 11,841 8,960 -2,881 -24.3 

Madhya Pradesh 42,054 34,841 -7,213 -17.2 7,564 6,810 -754 -10.0 

Maharashtra 121,901 95,761 -26,140 -21.4 18,049 13,766 -4,283 -23.7 

Daman & Diu 1,797 1,576 -221 -12.3 240 215 -25 -10.4 

D.N. Haveli 3,574 3,457 -117 -3.3 504 443 -61 -12.1 

Goa 2,801 2,754 -47 -1.7 466 413 -53 -11.4 

Western Region 254,475 213,715 -40,760 -16.0 37,240 30,153 -7,087 -19.0 

Andhra Pradesh 71,511 66,673 -4,838 -6.8 11,083 9,997 -1,086 -9.8 

Karnataka 43,168 40,578 -2,590 -6.0 6,892 6,548 -344 -5.0 

Kerala 17,645 15,562 -2,083 -11.8 3,188 2,751 -437 -13.7 

Tamil Nadu 69,668 64,208 -5,460 -7.8 9,799 9,211 -588 -6.0 

Pondicherry 2,020 1,773 -247 -12.2 304 275 -29 -9.5 

Lakshadweep 24 24 0 0 6 6 0 0 

Southern Region 204,012 188,794 -15,218 -7.5 28,958 26,245 -2,713 -9.4 

Bihar 10,527 8,801 -1,726 -16.4 1,842 1,333 -509 -27.6 

DVC 14,002 13,699 -303 -2.2 2,217 2,178 -39 -1.8 

Jharkhand 5,361 5,110 -251 -4.7 889 887 -2 -0.2 

(1/2) 



Orissa 20,519 20,214 -305 -1.5 3,062 2,987 -75 -2.4 

West Bengal 31,289 30,290 -999 -3.2 5,387 5,379 -8 -0.1 

Sikkim 343 330 -13 -3.8 97 95 -2 -2.1 

Andaman- Nicobar 236 184 -52 -22.0 40 38 -2 -5 

Eastern Region 82,041 78,444 -3,597 -4.4 12,901 11,789 -1,112 -8.6 

Arunachal Pradesh 426 271 -155 -36.4 130 79 -51 -39.2 

Assam 5,107 4,567 -540 -10.6 958 797 -161 -16.8 

Manipur 556 477 -79 -14.2 128 95 -33 -25.8 

Meghalaya 1,713 1,386 -327 -19.1 457 293 -164 -35.9 

Mizoram 330 269 -61 -18.5 100 64 -36 -36.0 

Nagaland 475 436 -39 -8.2 95 86 -9 -9.5 

Tripura 800 728 -72 -9.0 167 156 -11 -6.6 

North-Eastern Region 9,407 8,134 -1,273 -13.5 1,820 1,358 -462 -25.4 

All India 777,039 691,038 -86,001 -11.1 109,809 96,785 -13,024 -11.9 

# Lakshadweep and A & N Islands standalone systems, power supply position of these, does not form part 

of regional requirement and availability 

Note: Both peak met and energy availability represent the net consumption (including the transmission losses) in the various States. 

Net export has been accounted for in the consumption of importing States. 

(2/2) 


167


Status of Capacitor Installation as on 31.03.2009 

State /U.T. / System/ Region 

Installed 

as on 

1/04/2008 

Requirement 

during 

2008-2009 

Actual Addition 

during 

200/8-2009 

Annexure 4B 


(1/1) 

(All figures in MVAR) 

Balance 

(A) (B) (C) (D=B-C) 

Northern Region 

Delhi 3,456 399 0.00 399.00 

Haryana 2,773 1402 391.00 1,011.00 

Punjab 5,450 863 125.62 737.38 

Rajasthan 3,732 648 29.40 618.60 

U.P. 5,812 1868 0.00 1,868.00 

Uttarakhand 353 147 0.00 147.00 

Himachal Pradesh 514 136 0.00 136.00 

Jammu & Kashmir 147 1173 0.00 1,173.00 

Chandigarh 102 78 0.00 78.00 

Total (NR) 22,339 6714 546.02 6,167.98 

Western Region 

Gujarat 4,621.507 435 0.00 435 

Madhya Pradesh 4,145.400 110 0.00 110 

Chhattisgarh 733.435 90 20.00 70 

Maharashtra (*) 5,954.446 375 0.00 375 

Goa 149.800 0 0.00 0 

Total (WR) 15,604.588 1,010 20.00 990 

Southern Region 

Andhra Pradesh 6,593.400 100 0.00 100 

Karnataka 4,486.460 7.20 0 

Kerala 1,005.000 15 0.00 15 

Tamil Nadu (#) 3,949.900 17.6 0.00 17.6 

Total (SR) 16,034.760 132.6 7.20 132.6 

Total 53,978.348 7,856.6 573.22 7,290.58 



Scheme 

PFRs under 50 000 MW Hydroelectric Initiative 

Low Tariff PFR Schemes 

State 

Installed Capacity 

Units x Total 

Size (MW) (MW) 

Estimated 

Cost 

(Rs. Cr.) 

Annexure-5A 

(Item No.5.2) 

(1/3) 

Tariff: Below Rs.2.50 

Annual 

Energy 

(GWh) 

Tariff 

(Rs/ 

kWh) 


1 Kalai Ar. Pradesh 10 x 260.00 2600 6637.67 10608.64 1.01 

2 Naying Ar. Pradesh 4 x 250.00 1000 3016.96 5077.15 1.18 

3 Hutong Ar. Pradesh 12 x 250.00 3000 7792.29 9901.00 1.28 

4 Oju-II Ar. Pradesh 4 x 250.00 1000 3492.99 4629.93 1.46 

5 Tato-II Ar. Pradesh 4 x 175.00 700 2608.60 3465.90 1.48 

6 Hirong Ar. Pradesh 4 x 125.00 500 2072.78 2535.80 1.62 

7 Bhareli-II Ar. Pradesh 5 x 120.00 600 1698.35 2345.00 1.67 

8 Etalin Ar. Pradesh 16 x 250.00 4000 14069.14 16071.60 1.70 

9 Kapakleyak Ar. Pradesh 4 x 40.00 160 463.52 627.95 1.74 

10 Bhareli-I Ar. Pradesh 8 x 140.00 1120 3372.45 4112.40 1.85 

11 Demwe Ar. Pradesh 12 x 250.00 3000 9539.40 10823.82 1.97 

12 Niare Ar. Pradesh 4 x 200.00 800 3498.55 3356.62 2.02 

13 Oju-I Ar. Pradesh 4 x 175.00 700 3526.28 3291.58 2.08 

14 Naba Ar. Pradesh 4 x 250.00 1000 4399.89 3995.25 2.14 

15 Dibbin ** Ar. Pradesh 2 x 50.00 100 371.52 335.72 2.23 

16 Talong ** Ar. Pradesh 3 x 100.00 300 891.04 915.50 2.24 

17 Kameng Dam Ar. Pradesh 5 x 120.00 600 2264.00 2345.55 2.29 

18 Badao ** Ar. Pradesh 4 x 30.00 120 443.98 441.00 2.32 

19 Attunli Ar. Pradesh 4 x 125.00 500 2725.26 2247.32 2.35 

Total (19 Schemes) 21800 

Himachal Pradesh 

20 Chamba HP 3 x 42.00 126 420.90 646.82 1.48 

21 Thopan Powari HP 3 x 160.00 480 1796.98 1786.26 1.81 

22 Gondhala HP 3 x 48.00 144 482.50 570.19 1.92 

23 Jangi Thopan HP 3 x 160.00 480 1805.54 1779.45 2.00 

24 Tidong-II HP 2 x 35.00 70 309.84 256.18 2.02 

25 Bajoli Holi HP 3 x 60.00 180 649.22 762.98 2.03 

26 Yangthang HP 3 x 87.00 261 1120.20 938.02 2.08 


169


27 Gharopa HP 3 x 38.00 114 493.59 534.25 2.09 

28 Khab-I HP 3 x 150.00 450 1765.89 1551.00 2.24 

29 Luhri ** HP 3 x 155.00 465 2039.98 1825.13 2.41 

30 Khoksar HP 3 x 30.00 90 373.66 351.91 2.46 


Jammu & Kashmir 

31 Kiru ** J&K 4 x 107.50 430 857.58 1935.77 0.77 

32 Kawar ** J&K 4 x 80.00 320 891.37 1426.56 1.09 

33 Bichlari J&K 2 x 17.50 35 94.40 148.29 1.11 

34 Ratle ** J&K 4 x 140.00 560 1987.92 2483.37 1.40 

35 Shamnot J&K 4 x 92.50 370 1592.91 1650.19 1.69 


Karnataka 

36 Agnashini Karnataka 4 x 150.00 600 910.71 1431.00 1.07 

37 Gundia ** Karnataka 2 x 150.00 300 531.68 616.00 1.41 

38 Gangavali Karnataka 2 x 200.00 400 709.68 759.00 1.46 

39 

Kalinadi Stage- 

III 

Karnataka 2 x 150.00 300 590.05 610.00 1.67 


Meghalaya 

40 Mawhu ** Meghalaya 3 x 40.00 120 434.24 482.96 1.40 

41 Umjaut Meghalaya 3 x 23.00 69 276.97 276.70 1.51 

42 Umduna Meghalaya 3 x 19.00 57 226.68 231.24 1.68 

43 Nongkolait Meghalaya 2 x 60.00 120 392.80 332.87 1.97 

44 Selim Meghalaya 2 x 85.00 170 652.07 534.68 2.02 

45 Rangmaw Meghalaya 2 x 32.50 65 268.37 229.60 2.32 

46 Nongnam Meghalaya 2 x 25.00 50 272.07 212.59 2.44 


Sikkim 

47 Teesta-I Sikkim 4 x 80.00 320 1206.59 1298.12 1.80 

48 Dikchu ** Sikkim 3 x 35.00 105 518.50 469.00 2.15 

49 Panan ** Sikkim 4 x 50.00 200 846.08 762.00 2.15 

50 Lachen Sikkim 3 x 70.00 210 1046.93 865.94 2.35 


Uttaranchal 

51 Badrinath ** Uttaranchal 2 x 70.00 140 357.33 702.70 0.81 

52 Garba Tawaghat Uttaranchal 3 x 210.00 630 1447.77 2483.11 0.90 

53 Arakot Tiuni Uttaranchal 3 x 24.00 72 310.51 382.90 1.00 

54 Harsil ** Uttaranchal 3 x 70.00 210 578.20 920.57 1.10 

(2/3) 



(3/3) 

55 Chhunger- Chal Uttaranchal 2 x 120.00 240 725.53 853.28 1.13 

56 Rishi Ganga - 1 Uttaranchal 2 x 35.00 70 277.01 327.30 1.18 

57 Karmoli Uttaranchal 2 x 70.00 140 465.60 621.00 1.30 

58 Mapang - 

Bogidiyar 

Uttaranchal 2 x 100.00 200 667.19 882.04 1.30 

59 Taluka Sankri Uttaranchal 2 x 70.00 140 378.14 559.47 1.33 

60 Deodi Uttaranchal 2 x 30.00 60 242.34 296.76 1.37 

61 Sela Urthing Uttaranchal 2 x 115.00 230 696.73 816.73 1.40 

62 Urthing Sobla Uttaranchal 4 x 70.00 280 888.45 1360.20 1.49 

63 

Sirkari Bhyol 

Rupsia-bagar 

Uttaranchal 3 x 70.00 210 899.63 967.97 1.55 

64 Rupsia-bagar 

Khasiya-bara ** 

Uttaranchal 2 x 130.00 260 1101.55 1195.63 1.59 

65 Gangotri ** Uttaranchal 1 x 55.00 55 252.61 264.76 1.62 

66 Gohana Tal Uttaranchal 2 x 30.00 60 270.38 269.35 1.64 

67 Bokang Baling Uttaranchal 3 x 110.00 330 1120.75 1124.62 1.68 

68 Jelam Tamak Uttaranchal 2 x 30.00 60 277.92 268.12 1.71 

69 Jakhol Sankri Uttaranchal 3 x 11.00 33 171.00 144.24 1.71 

70 Bhairon-ghati ** Uttaranchal 2 x 32.50 65 304.32 293.18 1.80 

71 Maleri Jelam Uttaranchal 2 x 27.50 55 257.85 243.07 1.80 

72 Naitwar-Mori Uttaranchal 3 x 11.00 33 202.20 151.00 1.85 

73 Bogudiyar - 

Sirkari Bhyal 

Uttaranchal 2 x 85.00 170 859.27 744.00 1.99 

74 Nand Prayag Uttaranchal 3 x 47.00 141 670.04 794.00 2.05 

75 Jadh Ganga Uttaranchal 2 x 25.00 50 277.48 220.88 2.19 

76 Lata Tapovan ** Uttaranchal 4 x 77.50 310 1021.30 1123.00 2.21 

77 Rishi Ganga - II Uttaranchal 1 x 35.00 35 212.98 164.64 2.22 

78 Tamak Lata Uttaranchal 4 x 70.00 280 988.21 1040.70 2.30 


Total - 78Nos. 34020 

** DPRs Prepared 


171


Sl 

No. 

A. Hydro Capacity Addition during the year 2008-09 

(Programme :1097 MW) 

Name of Project/ 

State/Organisation 

(Nos.xSize= Capacity MW) 

Units Commissioned during 2008-09 

State Sector 

1 Baglihar 

J&K/ JKPDC 

(3x150 MW) 

2 Ghatghar PSS 

Maharashtra/ GOMID 

(2x125 MW) 

3 Priyadarshini Jurala 

A.P./APGENCO 

(6x39 = 234 MW) 

4 Varahi Extn. 

Karnataka /KPCL 

(2x115 MW) 

Sl 

No. 

Unit 

No. 

1 

2 

3 

1 

2 

Capacity 

(MW) 

150 

150 

150 

125 

125 

Target at 

Beginning of 

the year 

09/2008 

10/2008 

11/2008 

05/2008 

07/2008 

Date of 

Rotation 

09.09.08 

08.10.08 

03.11.08 

19.02.08 

05.06.08 

Annexure-5B 

(Item No.5.4) 

(1/1) 

Date of 

commissioning 

19.09.08 

26.10.08 

14.11.08 

13.05.08 

01.07.08 

2 39 07/2008 28.08.08 31.08.08 

1 

2 

115 

115 

Total (Commissioned): 8 Units 969 MW 

12/2008 

02/2009 

10.12.08 

30.12.08 

B. Hydro Capacity slippage from the year 2008-09 

Name of Project/ 

State/Organisation 

(Nos.xSize= Capacity MW) 

State Sector 

1 Kuttiyadi Addl. Extn. 

Kerala/KSEB 

(2x50 = 100 MW) 

2. Priyadarshini Jurala 

A.P./APGENCO 

(6x39 = 234 MW) 

Unit 

No. 

Capacity 

(MW) 

Target at 

beginning of 

the year 

11.01.09 

09.02.09 

Reasons for slippage 

1 50 03/2009 Slow progress of Penstock liners 

erection. 

3 

4 

39 

39 

Total slippage from 2008-09 3 Units 128 MW 

SUMMARY 

Capacity Programmed : 1097 MW 

Capacity Commissioned : 969 MW 

Capacity Slipped : 128 MW 

11/2008 

03/2009 

-Single shift working. 

-Visa Problem of Chinese 

personnel 



Annexure-5C 

(Item No.5.4.1) 

(1/3) 

Hydro Capacity Addition Programme for the year 2009-10 

S. 

No. 

Particular 

A. Slipped units of 2008-09 

1. Priyadarshini 

Jurala 

APGENCO, A.P. 

6x39 = 234 MW 

Unit # 3 

Unit # 4 

Capacity 

(MW) 

39 

39 

Likely 

Commissioning 

May, 09 

Oct., 09 

2. Kuttiyadi Addl. 

Ext. 

KSEB, Kerala 

2x50 = 100 MW 

Unit # 1 50 June 09 

B. Projects in year 2009-10 as per 11 th Plan 

1. Sewa-II 

NHPC, J&K 

3x40 = 120 MW 

Unit # 1 

Unit # 2 

Unit # 3 

40 

40 

40 

Jan. 10 

Feb-10 

Mar-10 

Brief Status of Works 

Power House - Power House concreting in progress. 

Unit #1- Synchronized on 28.03.2008. COD on 18.08.2008. 

Unit #2- Synchronized on 31.08.2008. COD on 11.09.2008. 

Unit #3- Shaft assembly lowered. Stator positioned and alignment 

of units is in progress. 

Unit #4 - Draft tube erection and concreting completed. 

Stay cone erected and concreting is in progress. 

Unit 5 #6- Draft tube erection and concreting completed. Raising 

of side walls & columns are in progress. 

Laying of cables from Switchyard to P.H. is in progress. 

Intake, HRT, Surge shaft civil works completed. 

Penstock (surface)- BVC building works are in progress. 

Penstock track excavating almost completed. Erection of steel 

liner is in progress. Concreting of 16/28 anchor blocks completed. 

About 1474 m penstock erection out of 2115 m completed. 

Unit # 1: Alignment of unit completed. Boxing up is in progress. 

Cabling & piping work is in progress. 

Unit # 2: Alignment of unit completed. Boxing up is in progress. 

Overall 75% turbine and generator erection work completed. 

Transmission Line: Work for 14.5 Km multi-circuit line from 

Kakkayam to Patthiper started in November, 2008. For 25.23 km 

D/C line Patthiper to Vadkora, tree cutting in undisputed portion 

started. 

Civil works: awarded to M/s GIL-Srinivasa JV (Dam, HRT and 

Power House) on 08.09.2003 and M/s Patel Engg. (Tail Race and 

other works) on 08.09.2003. 

Diversion Tunnel- Tunnel day lighted in July, 2004 & River 

diverted on 27.11.2004. 

Dam- Dam excavation completed and 126729 Cu.m. concreting 

out of 127773 Cu.m. completed. 

De-silting Chamber-1: Excavation completed. 

De-silting Chamber-2: Excavation completed. 

Head Race Tunnel- Excavation (10084 m) completed. 

HRT Lining: 

5865 m lining completed out of 10084 m. 

Surface Power House- Excavation completed and 35296 Cu.m. 

concreting including switchyard completed out of 36222 Cu.m. 

Unit #1 #2 & #3 Boxed up. 

E&M works: awarded to M/s BHEL on 23.06.2004. 

HM works: awarded to M/s Om Metals & Minerals Ltd. on 

24.11.2004. 


173


2 Teesta Low Dam- 

III 

NHPC, W.B. 

4x33 = 132 MW 

Unit # 1 

Unit # 2 

Unit # 3 

Unit # 4 

33 

33 

33 

33 

Feb. 10 

Feb.10 

Mar-10 

Mar-10 

3. Priyadarshini 

Jurala 

APGENCO, A.P. 

6x39 = 234 MW 

Unit # 5 39 Feb-. 10 

4. Kuttiyadi Addl. 

Ext. 

KSEB, Kerala 

2x50 = 100 MW 

Unit # 2 50 Jul. 09 

5. Myntdu (Leishka) 

St-I 

MeSEB, 

Meghalaya 

2x42 = 84 MW 

Unit # 1 

Unit # 2 

42 

42 

Dec-09 

Feb-10 

(2/3) 

Civil works: awarded to M/s Patel Engg. Ltd. on 28.10.2003. 

1 st stage river diverted on 20.12.04, 2 nd stage on 30.05.05 & 3 rd 

stage in June, 2008. 3 rd stage diversion washed in July, 2008. 

Dam Cellular wall concreting: 62887 Cu.m. concreting 

completed out of 67315 Cu.m. 

Barrage- Barrage Blocks III to VII: Excavation & concreting 

Completed. 

Intake Structure -Excavation completed. 

39012 Cu.m. concreting out of 39575 Cu.m. completed. 

Penstock –Excavation completed and erection is in progress. 

Power House- Excavation completed (307067 cum). 

69892 Cu.m. concerting completed out of 97329 Cu.m. 

Tail Race channel: 801756 Cu.m. excavation out of 835000 

Cu.m. completed. 

E&M work: awarded to M/s VA Tech. on 30.7.04. Draft tube 

erection for all units completed & earthmat work is in progress. 

EOT crane erection in service bay and Unit # 1 & 2 completed. 

Scroll case in Unit-I & Unit-II is in progress. 

HM work: awarded to consortium of M/s Texmaco & M/s Alstom 

Ltd. on 11.02.05. Design & fabrication of various components is 

in progress. In Bay 5-7, erection of radial gates is in progress. 

As indicated above. 

As indicated above. 

Main Dam: Excavation completed and 92.18% (306324.94 / 

332311 Cu.m.) concreting completed. 

HRT: Excavation completed. Concreting overt & invert 

3293/3313.46 Cu.m. 99.38% completed. 

Surge Shaft: 1427/2030 Cu.m. concreting completed. 

HPT: Excavation & invert concreting completed. 

Surface Penstock: 99758.57/114194 Cu.m. excavation 

completed. 

7800/19965 Cu.m. concreting completed. 

Power House: Excavation completed. 12186.87/13000 cum 

substructure and 2510.30/7148 Cu.m. super structure concreting 

completed. 

E&M : Works under advance stage.. 

HM works: Erection work for embedded parts in block 8,9,13 & 

14 is in progress. 

Spillway & Gates (Radial Gates) Fabrication & supply 

2150/2500 MT completed. 

Tail Race: Excavation completed. 

2472/4200 Cu.m. lining completed 



6. Allain Duhangan 

ADHPL, H.P. 

2x96 = 192 MW 

Unit # 1 

Unit # 2 

7. Malana-II 

Everst PC, H.P. 

2x50 = 100 MW 

Unit # 1 

Unit # 2 

96 

96 

50 

50 

Total (A+B) 845 

Nov. 09 

Dec. 09 

Dec.. 09 

Jan. 10 

(3/3) 

Financial closure : achieved on 21.11.2005 

HRT: Out of about 3963 m of boring of Allain HRT, 3746 m 

have been completed. Out of 4507 m of boring of Duhangan 

HRT, 2328 m has been completed. Concreting 1534m /3137 

m completed. 

Tail Race Access Tunnel : Excavation and overt lining completed. 

Gates erected. 

Power House: Excavation and concreting completed. 

Transformer : 6 out of 7 transformers installed. 

E&M: Both units boxed up. 

Switchyard: Structure, towers and erection of equipment is in 

progress. 

Transmission Lines: Foundations 420/565, Towers 386/565, 

Stringing 32.5 km out of 180 km completed. 

Excavation and concreting in Allain barrage, desilting chambers 

and intermediate reservoir is completed. Spillway concreting is 

near completion 

Financial closure on 03.08.2006. 

All works awarded. 

Dam: Excavation of dam almost completed and 33000/85000 

Cu.m. concreting done and balance is programmed to be 

completed by 31.07.2009. 

HRT: Out of 4.96 km of boring, 4.38 km has been completed. 

Concreting is yet to start. 

Power House: Excavation completed and concreting in progress. 

MAT, TRT, Cable duct completed. 

Pressures Shaft: Horizontal portion 226/226 m and vertical 

position 471/566m completed. Ferrule erection is in progress. 

E&M : Works awarded to M/s Abir Const. Private Ltd. on 

18.10.2006. Supply of TG sets completed. 

Stator of Unit-1 lowered & Rotor likely to be lowered shortly. 

Assembly of rotor for Unit-2 taken up. 

Construction Power: Construction Power supply to site 

completed. 


175


Sl. 

No. 

Annexure-5D 

(Item No.5.7) 

(1/4) 

HYDRO PROJECTS IDENTIFIED FOR BENEFITS DURING 12 th PLAN 

Name of scheme Type State Agency 

Installed 

Capacity 

(MW) 

Benefit in 

12th. Plan 

1 Bajoli Holi ROR H.P. IPP 180 180 

2 Chirgaon (Majhgaon) ROR H.P. HPPCL 42 42 

3 Dhaula Sidh ROR H.P. SJVNL 40 40 

4 Kutehr ROR H.P. IPP 260 260 

5 Luhri ROR H.P. SJVNL 776 776 

6 Renuka dam STO H.P. HPPCL 40 40 

7 Sainj ROR H.P. HPPCL 100 100 

8 Kashang - I ROR H.P. HPPCL 130 130 

9 Kashang-II & III ROR H.P. HPPCL 130 130 

10 Kashang -IV ROR H.P. HPPCL 48 48 

11 Shongtong Karcham ROR H.P. HPPCL 402 402 

12 Tangnu Romai ROR H.P. IPP 44 44 

13 Lambadug ROR H.P. IPP 25 25 

14 Tidong-I ROR H.P. IPP 100 100 

15 Chango Yangthang ROR H.P. IPP 140 140 

16 Baglihar-II ROR J & K PDC 450 450 

17 Kiru ROR J & K NHPC 600 600 

18 Kawar ROR J & K NHPC 520 520 

19 Kishan Ganga ROR J & K NHPC 330 330 

20 Pakhal Dul STO J & K NHPC 1000 1000 

21 Ratle ROR J & K To be decided 690 690 

22 Kirthai-I ROR J & K PDC 240 240 

23 New Ganderbal ROR J & K PDC 93 93 

24 Kotlibhel-St-1A ROR Uttarakhand NHPC 195 195 

25 Kotlibhel-St-1B ROR Uttarakhand NHPC 320 320 

26 Kotlibhel-St-II ROR Uttarakhand NHPC 530 530 

27 Lata Tapovan ROR Uttarakhand NTPC 171 171 

28 Vishnugad Pipalkoti ROR Uttarakhand THDC 444 444 



(2/4) 

29 Arkot Tiuni ROR Uttarakhand UJVNL 72 72 

30 Alaknanda (Badrinath) ROR Uttarakhand IPP 300 300 

31 Mapang Bogudiyar ROR Uttarakhand IPP 200 200 

32 Bogudiyar Sirkari ROR Uttarakhand IPP 170 170 

33 Bowala Nand Prayag ROR Uttarakhand UJVNL 300 300 

34 Devsari Dam ROR Uttarakhand SJVNL 252 252 

35 Hanol Tiuni ROR Uttarakhand IPP 60 60 

36 Jhelam Tamak ROR Uttarakhand THDC 126 126 

37 Lakhwar Vyasi STO Uttarakhand NHPC 420 420 

38 Nand Prayag Lingasu ROR Uttarakhand UJVNL 100 100 

39 Naitwar Mori (Dewra Mori) ROR Uttarakhand SJVNL 56 56 

40 Pala Maneri ROR Uttarakhand UJVNL 480 480 

41 Bhaironghati ROR Uttarakhand UJVNL 381 381 

42 Rupsiyabagar Khasiyabara ROR Uttarakhand NTPC 260 260 

43 Singoli Bhatwari ROR Uttarakhand IPP 99 99 

44 Tamak Lata ROR Uttarakhand UJVNL 280 280 

45 Tuini Plasu ROR Uttarakhand UJVNL 42 42 

46 Kishau Dam STO Uttarakhand THDC 600 600 

47 Tehri St-II PSS PSS Uttarakhand THDC 1000 1000 

48 Shahpur Kandi STO Punjab PSEB 168 168 

49 UBDC-III ROR Punjab IPP 75 75 

50 Hosangabad ROR MP NHDC 60 60 

51 Handia ROR MP NHDC 51 51 

52 Baurus ROR MP NHDC 55 55 

53 Dummugudem STO A..P. APID 320 320 

54 Pollavaram MPP STO A..P. APID 960 960 

55 Singareddy STO A..P. APID 280 280 

56 Achenkovil STO Kerala KSEB 30 30 

57 Pambar ROR Kerala KSEB 40 40 

58 Vythiri ROR Kerala KSEB 60 60 

59 Athirapally ROR Kerala KSEB 163 163 

60 Mankulam ROR Kerala KSEB 40 40 

61 Thottiar ROR Kerala KSEB 40 40 


177


(3/4) 

62 Kundah PSS PSS Tamil Nadu TNEB 500 500 

63 Gundia-I ROR Karnataka KPCL 200 200 

64 Gundia-II ROR Karnataka KPCL 200 200 

65 Ramam St-I ROR W. B. WBSEDCL 36 36 

66 Ramam St-III ROR W. B. NTPC 120 120 

67 Ramman Ultimate(IV) ROR W. B. WBSEDCL 30 30 

68 Panan ROR Sikkim IPP 280 280 

69 Dikchu ROR Sikkim IPP 96 96 

70 Rangit-II ROR Sikkim IPP 66 66 

71 Rangit-IV ROR Sikkim IPP 120 120 

72 Teesta St.-II ROR Sikkim IPP 480 480 

73 Teesta St.-IV ROR Sikkim NHPC 520 520 

74 Teesta-VI ROR Sikkim IPP 500 500 

75 Jorethang Loop ROR Sikkim IPP 96 96 

76 Thangchi ROR Sikkim IPP 99 99 

77 Bhimkyong ROR Sikkim IPP 99 99 

78 Bop ROR Sikkim IPP 99 99 

79 Pare ROR Ar.Pradesh NEEPCO 110 110 

80 Siang Lower STO Ar.Pradesh IPP 2400 600 

81 Siang Middle (Siyom) STO Ar.Pradesh IPP 1000 1000 

82 Dibbin ROR Ar.Pradesh IPP 125 125 

83 Londa (Talong) ROR Ar.Pradesh IPP 160 160 

84 Nyamjunchhu St-I ROR Ar.Pradesh IPP 98 98 

85 Nyamjunchhu St-II ROR Ar.Pradesh IPP 97 97 

86 Nyamjunchhu St-III ROR Ar.Pradesh IPP 95 95 

87 Tawang-I ROR Ar.Pradesh NHPC 750 750 

88 Tawang-II ROR Ar.Pradesh NHPC 750 750 

89 Tato-II ROR Ar.Pradesh IPP 700 700 

90 Hirong ROR Ar.Pradesh IPP 500 500 

91 Demwe Lower ROR Ar.Pradesh IPP 1640 1640 

92 Demwe Upper ROR Ar.Pradesh IPP 1640 1640 

93 Kameng Dam STO Ar.Pradesh IPP 480 480 

94 Khuitam ROR Ar.Pradesh IPP 60 60 



(4/4) 

95 Turu ROR Ar.Pradesh IPP 90 90 

96 Gongri ROR Ar.Pradesh IPP 90 90 

97 SaskangRong ROR Ar.Pradesh IPP 30 30 

98 Hirit ROR Ar.Pradesh IPP 28 28 

99 Dinchong ROR Ar.Pradesh IPP 90 90 

100 Nafra ROR Ar.Pradesh IPP 96 96 

101 Pema Shelphu(Barpu) ROR Ar.Pradesh IPP 97.5 97.5 

102 Kangtanshiri ROR Ar.Pradesh IPP 60 60 

103 Nyukcha Rong Chhu ROR Ar.Pradesh IPP 96 96 

104 Mago Chhu ROR Ar.Pradesh IPP 96 96 

105 Lower Kopili ROR Assam Assam GENCO 150 150 

106 Tipaimukh STO Manipur NEEPCO 1500 1500 

107 Loktak D/S ROR Manipur NHPC 66 66 

108 Umangi -I STO Meghalaya MeSEB 54 54 

109 Kynshi-I STO Meghalaya IPP 450 450 

Total 30919.50 

Abbreviation: 1. ROR – Run of River 2. STO - Storage 


179


Hydro Electric Schemes concurred 

by CEA during 2008-09 

Annexure-5E 

(Item No.5.17.2) 

(1/1) 

S.No. 

Name of Scheme/ 

State/ Executing 

Agency 

Installed 

Capacity 

(MW) 

Date of 

concurrence 

Hard Cost 

(As per 

DPR) 

Hard 

Cost (As 

per TEC) 

Saving 

in Hard 

Cost 

% 

Saving 

in Hard 

Cost 

1. Gundia HEP in 1x200=200 25.04.2008 991.23 958.67 32.56 3.28 

Karnataka by M/s. 

KPCL 

2. Singoli Bhatwari 3x33=99 11.07.2008 663.38 560.48 102.90 15.51 

HEP in Uttarakhand 

by M/s. L&T 

Uttaranchal Hydro 

Power Ltd. 

3. Alaknanda HEP in 3x100=300 08.08.2008 1235.42 883.24 373.18 30.18 

Uttarakhand by M/s. 

GMR Energy Ltd. 

4. Rupsiabagar 

3x87=261 16.10.2008 1554.82 1404.73 150.09 9.65 

Khasiyabara HEP in 

Uttarakhand by M/s. 

NTPC Ltd. 

TOTAL 860 MW 4445.85 3787.12 658.73 14.82 

180 “It is always the best policy to tell the truth, unless, of course, you are an exceptionally good liar.”


Annexure-6A 

(Item No.6.3) 

Projects based on Tariff Based Competitive Bidding 

(Case-II) by States 

(1/1) 

S.No. Name of the Project Location Capacity 

Haryana 

1. Jhajjar District Jhajjar 1150+15% 

Punjab 

2 Gidderbaha (Ghagga) Thermal Power Project – 

Stage-I & II, PSEB, Punjab 

Distt. Muktsar 

4x660 

3 Talwandi Saboo District Mansa 3x600 

4. Rajpura Rajpura, Patiala 2x600 

Madhya Pradesh 

5. Shahpura District, Jabalpur 1500 

Uttar Pradesh 

6. Bara 3x660 

7. Karchanna 2x660 

Chhattisgarh 

8. Bhaiyathan District, Surguja 2x660 

Maharashtra 

9. Aurangabad TPP Distt. Aurangabad 2x800 

10. Dhule TPP Distt,Dhule 2x800 

Karnataka 

11 Jewargi Distt. Gulbarga 1000 

12. Ghatprabha Distt. Belgaum 1320 

Bihar 

13 Thermal Power Project at Kajra, 

(Instead of Katihar Project Site) 

14 Thermal Power Project at Chausa, 

(Instead of Navinagar Project Site) 

Distt. Lakhisarai 2x660=1320 

Distt. Buxar 2x660=1320 

15 Thermal Power Project at Pirpainti Distt. Bhagalpur 2x660=1320 

Total 

22,390 MW 

“The one exclusive sign of thorough knowledge is the power of teaching.” 

181


Sl 

No 

THERMAL UNITS TARGET & ACHIEVEMENT DURING 2008-09 

Project 

Name 

State/ 

Implementing Agency 

Unit. 

No. 

Target 

Capacity 

(MW) 

Contrac-tual 

schedule of 

synchronisation 

Annexure-6B 

(Item No.6.5) 

Actual date 

of Commissioning 

(1/1) 

Actual 

Capacity 

Added 

(MW) 

A CENTRAL SECTOR 

1 Bhilai Extn. TPP Chhattisgarh / NSPCL U-1 250 02/2008 08/2008 20.04.08(A) 250 

(NTPC & SAIL JV) 

U-2 250 

Slipped 

2 Sipat STPS-I Chhattisgarh /NTPC U-1 660 04/2008 Slipped 

3 Sipat STPS-II Chhattisgarh /NTPC U-5 500 12/2007 27.12.08(A) 500 

4 Kahalgaon STPS-II (Ph-I & II) Bihar/ NTPC U -7 500 03/2007 Slipped 

5 Chandrapura TPS Extn Jharkhand / DVC U- 7 250 11/2006 Slipped 

U- 8 250 01/2008 

6 Barsingsar Lignite Rajasthan/ NLC U-1 125 08/2008 Slipped 

U-2 125 03/2009 

Sub Total (A) 2910 750 

B STATE SECTOR 

1. GHTP(Lehra Mohabbat)TPS-II Punjab/ PSEB U-4 250 01/2008 31.07.08(A) 250 

2 Kutch Lignite Extn Gujarat/ GSECL U-4 75 07/2007 Slipped 

3 Sagardighi TPP WB / WBPDCL U-2 300 04/2007 20.07.08(A) 300 

4 Bakreshwar TPS-II WB / WBPDCL U-5 210 06/2007 Slipped 

5 Valuthur CCPP Extn. TN/TNEB GT 

ST 

59.8 

32.4 

11/2007 

02/2008 

06.05.08(A ) 

16.02.09(A) 

59.8 

32.4 

6 Amarkantak TPS Extn. MP/ MPPGCL U-5 210 02/2007 15.06.08(A) 210 

7 Giral Lignite- II Rajasthan/ RRVUNL U-2 125 06/2008 Slipped 

8 Chhabra TPS Rajasthan/ RRVUNL U-1 250 09/2008 Slipped 

U-2 250 12/2008 

9 Surat Lignite TPP Extn. Gujarat/ GIPCL U-3 125 09/2008 Slipped 

U-4 125 01/2009 

10 Kota TPP Rajasthan/ RRVUNL U-7 195 11/2008 Slipped 

11 Suratgarh TPP –IV Rajasthan/ RRVUNL U-6 250 09/2008 Slipped 

12 Vijaywada TPP –IV AP/ APGENCO U-1 500 08/2008 Slipped 

Sub Total (B) 2957.2 852.2 

C Private Sector 

1 OP Jindal (Raigarh) TPP Ph.I Chhattisgarh/Jindal Power U-4 250 12/2007 17.06.08(A) 250 

& II 

2. Sugen CCPP * Gujarat /Torrent Power Gen. 

Ltd. 

Block-1 

Block-2 

Block-3 

376 

376 

376 

09/2007 

12/2007 

02/2008 

04.02.09 (A) 

Slipped 

Slipped 

382.5 

3 Gautami CCPP AP/ Gautami Power Ltd GT -1 

GT- 2 

ST 

4 Konaseema CCPP AP/Konaseema EPS GT-1 

GT-2 

ST 

5 Pathadi TPS Ph-I ( Lanco 

Chattisgarh/ Lanco 

-Amarkantak Mega TPP) Amarkantak Power Pvt. Ltd. 

145 

145 

174 

140 

140 

165 

02/2006 

02/2006 

07/2006 

09/2005 

12/2005 

03/2006 

Slipped 

Slipped 

U-1 300 06/2008 Slipped 

6 Trombay TPS Extn. Maharastra/ Tata Power Co U-8 250 08/2008 26.03.09(A) 250 

7 Torangallu Extn. Karnataka/ JSW Energy Ltd U-1 300 07/2008 Slipped 

U-2 300 10/2008 

Sub Total (C) 3437 882.5 

GRAND TOTAL(A+B+C) 9304.2 2484.7 

* Capacity has been revised from 376 to 382.5 MW. 

182 “The doorstep to the temple of wisdom is the knowledge of our own ignorance.”


Annexure-6C 

(Item No.6.5.1) 

THERMAL CAPACITY ADDITION PROGRAMME FOR THE YEAR 2009-10 

AS ON 30th April, 2009 

Sector/State Project Name Implementing 

Agency 

COMMISSIONING ASSURED 


Unit 

Targeted 

Cap. 

(MW) 

Act(A)/Ant. 

Act(A)/ 

Ant. 

Comm. 

Date 

Bihar Kahalgaon St-2,Ph-2 NTPC U-7 500 31-03-09(A) 06/2009 

Chhattisgarh Bhilai TPP Expn NSPCL U-2 250 28-03-09(A) 06/2009 

Jharkhand Chandrapura TPS Extn. DVC U-7 250 06-01-09(A) 07/2009 

U-8 250 08/2009 10/2009 

Rajasthan Barsingsar Lignite NLC U-1 125 07/2009 10/2009 

UP NCP Project St-II, U-5 NTPC U-5 490 10/2009 01/2010 

STATE SECTOR 

Sub Total : 1865 

AP Vijayawada TPP -IV APGENCO U-1 500 06-04-09(A) 06/2009 

Gujarat Kutch Lignite TPS Extn GSECL U-4 75 22-10-08(A) 05/2009 

Surat Lignite TPP Extn. GIPCL U-3 125 09/2009 12/2009 

Utran CCPP Extn GSECL GT 228 05/2009 09/2009 

ST 146 08/2009 09/2009 

Haryana Rajiv Gandhi TPS,Hissar HPGCL U-1 600 10/2009 12/2009 

Maharastra New Parli TPP MSPGCL U-2 250 07/2009 10/2009 

Paras TPS Expn,U-2 U-2 250 10/2009 01/2010 

Rajasthan Chhabra TPS RRVUNL U-1 250 16-04-09(A) 07/2009 

Giral Lignite-II U-2 125 26-12-08(A) 05/2009 

Kota TPP U-7 195 05/2009 07/2009 

Suratgarh TPP U-6 250 31-03-09(A) 06/2009 

WB Bakereshwar TPS WBPDCL U-5 210 30-03-09(A) 06/2009 


(1/3) 

“Children are our most valuable natural resource.” 

183


PRIVATE SECTOR 

AP Gautami CCPP Gautami Power 

Ltd 

Chhattisgarh 

Gujarat 

Konaseema CCPP 

Lanco Kondapalli Ext. 

Lanco Amarkantak TPS 

Ph-1,U-1 

Lanco Amarkantak TPS 

Ph-1,U-2 

Mundra TPP Ph-1 

(U-1&2) 

Konaseema 

EPS 

Lanco 

Kondapalli 

Lanco 

Amarkantak 

Power Pvt. Ltd. 

Lanco 

Amarkantak 

Power Pvt. Ltd. 

Adani Power 

Ltd 

Gujarat Sugen CCPP(Akhakhol) Torrent Power 

Gen. Ltd. 

Karnataka Toranagallu TPP JSW Energy 

(Vijayanagar) 

Ltd. 

Orissa Sterlite TPP Sterlite Energy 

Ltd. 

Rajasthan Jallipa-Kapurdi TPP Raj West 

Power Ltd. 

(JSW) 

GT-1 145 30-10-08(A) 06/2009 

GT-2 145 17-11-08(A) 06/2009 

ST 174 23-02-09(A) 06/2009 

GT-1 140 06-03-09(A) 07/2009 

GT-2 140 04/2009 07/2009 

ST 165 05/2009 07/2009 

GT 233 09/2009 12/2009 

ST 133 11/2009 12/2009 

U-1 300 04/2009 06/2009 

U-2 300 10/2009 12/2009 

U-1 330 05/2009 08/2009 

U-2 330 07/2009 10/2009 

Blk-II 382.5 29-01-09(A) 05/2009 

Blk-III 382.5 05/2009 06/2009 

U-1 300 29-03-09(A) 27.04..09 

(A) 

U-2 300 09/2009 12/2009 

U-1 600 09/2009 12/2009 

U-1 135 05/2009 06/2009 

U-2 135 08/2009 09/2009 

U-3 135 10/2009 11/2009 

U-4 135 11/2009 12/2009 

WB Budge-Budge- III CESC U-3 250 06/2009 08/2009 


Total (Assured): 10359 

(2/3) 

184 “Honesty is the first chapter in the book of wisdom.”


COMMISSIONING WITH EFFORTS 


Rajasthan Barsingsar Lignite NLC U-2 125 10/2009 01/2010 

WB Mejia Extn DVC U-1 500 10/2009 02/2010 

STATE SECTOR 


AP Kakatiya TPP APGENCO U-1 500 01/2010 03/2010 

Gujarat Surat Lignite TPP Extn. GIPCL U-4 125 12/2009 03/2010 

Haryana Rajiv Gandhi TPS,Hissar HPGCL U-2 600 01/2010 03/2010 

Rajasthan Chhabra TPS RRVUNL U-2 250 12/2009 03/2010 



Delhi Rithala CCPP NDPL GT+ST 108 12/2009 01/2010 

Rajasthan Jallipa-Kapurdi TPP Raj West 

Power Ltd. 

(JSW) 

UP Rosa TPP Ph-I Rosa Power 

Supply 

Co.Ltd.- 

Reliance 

Energy 


Total (With Efforts): 2643 

Total(2009-10): 13002 

U-5 135 01/2010 02/2010 

U-1 300 12/2009 03/2010 

(3/3) 

“A person without a sense of humor is like a wagon without springs-jolted by every pebble in the road.” 

185


Sl. 

No. 

Annexure-6D 

(Item No. 6.11.2) 

(1/2) 

DETAILS OF UNITS IDENTIFIED FOR ENERGY EFFICIENT R&M 

State/ 

Utility 

Name of TPS 

Unit 

No. 

Capacity 

(MW) 

Rated 

Date of 

Commissioning 

Boiler 

Make 

Age as on 

31.03.09 

Remarks 

1 2 3 4 5 7 8 9 10 11 

1 MSPGCL KORADI 5 200 15/07/78 BHEL BHEL 30.7 

2 GSECL UKAI 3 200 21/01/79 BHEL BHEL 30.2 


4 MPEB SATPURA 6 200 30/03/79 BHEL BHEL 30.0 

5 MSPGCL NASIK 3 210 26/04/79 BHEL BHEL 30.0 Identified for EER&M 

during 12 th Plan under 

KfW fund. 

6 TNEB TUTICORIN 1 210 09/07/79 BHEL BHEL 29.7 

7 MSPGCL BHUSAWAL 2 210 30/08/79 BHEL BHEL 29.6 

8 APGENCO DR.N.TATA RAO 1 210 01/11/79 BHEL BHEL 29.4 

9 MSPGCL NASIK 4 210 10/07/80 BHEL BHEL 28.7 


11 MSPGCL PARLI 3 210 20/09/80 BHEL BHEL 28.5 

12 APGENCO DR.N.TATA RAO 2 210 10/10/80 BHEL BHEL 28.5 


14 MSPGCL NASIK 5 210 31/01/81 BHEL BHEL 28.2 

15 DVC DURGAPUR 4 210 12/05/81 BHEL BHEL 27.9 

16 MSPGCL KORADI 6 210 30/03/82 BHEL BHEL 27.0 Identified for EER&M 


World Bank fund. 


18 MSPGCL BHUSAWAL 3 210 04/05/82 BHEL BHEL 26.9 

19 WBSEB BANDEL 5 210 10/08/82 AVB BHEL 26.7 Identified for EER&M 

during 11th Plan under 

World Bank fund. 

20 MSPGCL KORADI 7 210 13/01/83 BHEL BHEL 26.2 


22 MSPGCL CHANDRAPUR 1 210 15/08/83 AVB BHEL 25.6 

23 WBPDC KOLAGHAT 3 210 24/01/84 AVB BHEL 25.2 Identified for EER&M 


KfW fund. 


25 MSPGCL CHANDRAPUR 2 210 17/07/84 AVB BHEL 24.7 

T.G. 



(2/2) 



28 MSPGCL CHANDRAPUR 3 210 03/05/85 BHEL BHEL 23.9 

29 WBPDC KOLAGHAT 2 210 16/12/85 AVB BHEL 23.3 

30 MSPGCL CHANDRAPUR 4 210 08/03/86 BHEL BHEL 23.1 

31 DVC BOKARO “B” 1 210 24/03/86 ABL BHEL 23.0 Identified for EER&M 


KfW fund. 

32 TNEB METTUR 1 210 04/01/87 BHEL BHEL 22.3 





37 DVC BOKARO “B” 2 210 11/07/90 ABL BHEL 18.7 

38 WBPDC KOLAGHAT 1 210 15/08/90 AVB BHEL 18.6 

39 WBPDC KOLAGHAT 5 210 17/03/91 BHEL BHEL 18.1 




43 DVC BOKARO “B” 3 210 31/03/93 ABL BHEL 16.0 


TOTAL 9200 


187


Annexure 8A 


(1/3) 

HYDRO POWER STATIONS IN OPERATION FOR WHICH CONSULTANCY 

SERVICES HAVE BEEN RENDERED BY CEA 

Sl. No. Name of the Power Station Installed capacity (MW) Year of Commissioning 

IN INDIA 

NORTHERN REGION 

1. Baira Siul 3x60=180 1980-81 

2. Salal-I 3x115=345 1987 

3. W.Y. Canal-A 2x8=16 1986 

4. W.Y. Canal-B 2x8-16 1987 

5. W.Y. Canal-C 2x8=16 1989 

6. Giri Bata 2x30=60 1978 

7. Lower Jhelum 3x35=105 1978-79 

8. Upper Sindh-1 2x11=22 1973-74 

9. Western Yamuna Canal 2x8=16 2004 

10. Chenani 5x4.6=23 1971-75 

11. Stakna 2x2=4 1986-87 

12. Kargil 3x1.25=3.75 1995 

13. R.P. Sagar 4x43=172 1968-69 

14. J.Sagar 3x33=99 1972-73 

15. Mahibajaj I 2x25=50 1989 

16. Mahibajaj II 2x45=90 1986 

17. Anoopgarh I 3x1.5=4.5 1987-88 

18. Anoopgarh II 3x1.5=4.5 1987-88 

19. RMC Mangrol 3x2=6 1992 

20. Surat Garh 2x2=4 1992 

21. Ranjit Sagar 4x150=600 2000 

22. Upper Singh-II 2x35=70 2000-01 

23. Nathpa Jhakri 6x250=1500 2002-03 

24. Tehri Stage-I 4x250=1000 2007-08 

25. Ukai 4x75=300 1974-76 



(2/3) 

26. Kadana 4x60=240 1990-96 

27. Ukai LBC 2x2.5=5 1987-88 

28. Gandhi Sagar 5x23=115 1960-64 

WESTERN REGION 

29. Bargi 2x45=90 1988 

30. Ban Sagar Tons 3x105=315 1991-92 

31. Hasdeo Bango 3x40=120 1994 

32. Paithon 1x12=12 1984 

33. Rajghat 3x15=45 1999 

34. Koyna IV 4x250=1000 1999-2000 

35. Sardar Sarovar CHPH 5x50=250 2003 

36. Indira Sagar 8x125=1000 2004-05 

37. Sardar Sarovar RBPH 6x200=1200 2006-07 

SOUTHERN REGION 

38. Lower Sileru 4x115=460 1976-78 

39. N.J. Sagar PSS 1x110+7x100=810 1978-85 

40. Kadamparai 4x100=400 1987-90 

41. Srisailam LBPH 6x150=900 2001-03 

42. Pykara Ultimate 3x50=150 2005-06 

EASTERN REGION 

43. Kosi 4x5=20 1970-78 

44. Subernrekha I 1x65=65 1977 

45. Subernrekha II 1x65=65 1980 

46. Sone Western Canal 4x1.65=6.6 1993 

47. Eastern Gandak 3x5=15 1994-96 

48. Sone Eastern 2x1.65=3.3 1996 

49. Rengali 5x50=250 1985-92 

50. Upper Kolab 4x80=320 1988-93 

51. Lower Lagyap 2x6=12 1979 

52. Upper Rongnichu 4x2=8 1993-94 

53. Myangchu 2x2=4 1993 


189


(3/3) 

54. Rammam II 4x12.75=51 1995-96 

55. Teesta Canal Falls I,II,III 3x3x7.5=67.5 1997-99 

56. Upper Indravati 4x150=600 2000-01 

57. Chandil 2x4=8 - 

NORTH EASTERN REGION 

58. Kyrdemkulai 2x30=60 1979 

59. Umiam St.I 4x9=36 1965 

60. Umiam St.II 2x9=18 1970 

61. Umiam Umtru St.IV 2x30=60 1992 

62. Gumti 3x5=15 1976-84 

63. Khandong 2x25=50 1984 

64. Kopili 2x50=100 1988 

65. Kopili Extn. 2x50=100 1996-97 

66. Loktak 3x35=105 1983&91 

67. Ranganadi 3x135=405 2002-03 

68. Doyang 3x25=75 2000 

IN NEIGHBOURING COUNTRIES 

NEPAL 

69. Gandak 3x5=15 

70. Trisuli 3x7=21 - 

BHUTAN 

71. Chukha 4x84=336 1986-88 

72. Gyesta 3x0.5=1.5 - 

73. Khaling 3x0.2=0.6 - 

74. Tala 6x170=1020 2007-08 

BURMA 

75. Sedawgyi 2x12.5=25 - 



ANNEXURE-8 B 

(Item- 8.9) 

LIST OF PROJECTS FOR WHICH DESIGN & ENGINEERING 

SERVICES WERE PROVIDED DURING 2008-09 

(1/2) 

Sl.No. Name of Project 

1. Transmission Project under 

Prime Minister’s Reconstruction 

Programme in J&K : 

2. Karaikal, CCPP 

( 32.5 MW ), Pondicherry 

3. Kutch Lignite TPP 

( 1 x 175 MW ), Gujarat 

4. Myntdu ( Leshka ) H.E. Project- 

Switchyard 132 /33 kV. 

Meghalaya 

5 Raghunathpur TPS, Phase-I, 

DVC ( 2 x 600 MW ), Purulia, 

W.B. 

Works carried out/in progress 

● Evaluation of comparison of price bids of various Grid stations 

- Amargarh, Alustang, Bandipora, Lissar Chandok, Battal Manwal 

● Checking of design & drawing of tower foundations for 

construction of Transmission Lines: 

- 132 kV Barn-Siot –Kalakote Transmission Line 

( Tower type DA, DB, DC, DD ) 

- 132 kV Ramban- Khellani- Kishtwar Transmission 

Line ( snow zone ) ( Tower type SA,SB, SC, SD) 

- 220 kV Hira Nagar Transmission Line 

( non snow zone ) ( Tower type DA,DB, DC, DD) 

● Checking of Design & drawing of various civil works of 

different substations ( eg. Control room building, equipment 

foundation, transformer foundation, gantry tower foundation, 

retaining walls, roads, drains, yard fencing, etc.) 

- Lissar, Bandipora & Shopian Bhalessa 

- Kishtwar Ramban . Budgam Bishnah 

- Amargarh & Alustang, Mir bazar. 

R.O. Plant at Pondicherry was inspected and meeting with project 

authority was held. Design calculation was examined, drawings 

related with gravity filter structural pile layout were released for 

construction. 

Following drawings/documents were approved and released for 

construction 

-Geotechnical investigation report and foundation detail of Ash Silo, 

Drawings of foundations of transformer, air compressor, HP Pump, 

seal water pump, Slurry pump 

Checked Drawings/ documents of - Design of foundation of tower 

type (T1-T8), -Design of support structure of 132 kV-CA, CT and 

PT. 

Following drawings/documents were examined and comments were 

sent 

-Wind Tunnel Test, RQP/DBR related with Area Grading and 

Chimney, Design of TG Building, Mill Bay Bunker, 

-Attended design review meeting held at Hyderabad on 1 st Oct 2008 

and at Kolkata during 22 nd to 23 rd October 2008 and 16 th to 17 th March 

2009. 


191


(2/2) 

6 Faridabad, TPS 

( 3 x 55 MW ), Haryana 

7 Rajiv Gandhi TPP, 

(1000/ 1200 MW), 

Hissar, Haryana: 

8 Deen Bandhu Chhotu Ram 

TPP, Yamuna Nagar 

( 2 x 300 MW ), Haryana 

Detailed estimate of raising of the ash dyke of Faridabad TPS was 

checked and visited the site to carry out on the spot assessment. 

Following design documents/ drawings were examined and 

comments were sent- 

-Coal Handling, NDCT-Drawings of Composite Piping Layout, 

Chimney, Field Quality plan for Ash Dyke, green belt, land scaping 

& rain water harvesting, Power House building drawing for TD- 

BFP supporting arrangement, ceiling air fan foundation layout & 

RC details, Test results of soil samples from Ash dyke, Analysis & 

design of supporting structure foundation for decantation well of ash 

pond. 

Following design documents/ drawings were examined and 

comments were sent 

- Ash Silo, Revised DCN along with STAAD calculation on cross 

bracing removal for Mill maintenance Raising of Ash pond –LDPE 

Layer level due to raise in Ground water level. 



Sl. 

No. 

ANNEXURE-9A 

(Item-9.1.4) 

OUTSTANDING DUES PAYABLE TO CENTRAL PUBLIC SECTOR 

UNDERTAKINGS(CPSUs) 

( in Rs. Crores) 

Name of state/ 

SEB/Utility 

NTPC NHPC PGCIL NEEPCO NPCIL DVC NLC SJVNL BBMB THDC TOTAL 

1. Andhra Pradesh -0.25 41.94 41.69 

2. 

Arunachal 

Pradesh 

7.03 7.03 

3. Assam 60.60 60.60 

4. Bihar 0.01 3.73 3.74 

5. 

HImachal 

Pradesh 

0.03 -4.22 0.58 0.39 0.08 -3.14 

6. 

Jammu & 

Kashmir 

57.37 14.94 10.28 6.80 20.78 110.18 

7. 

Karnataka 

(KPTCL) 

18.48 217.96 236.44 

8. Kerala 0.09 70.60 70.69 

9. Manipur 11.20 11.20 

10. Meghalaya -0.05 4.48 75.39 79.82 

11. Mizoram 4.67 4.67 

12. Nagaland 0.21 16.97 17.18 

13. Punjab 3.49 3.49 

14. Rajasthan 1.11 3.61 41.21 45.93 

Rajasthan 

Discom 

1.41 1.32 2.73 

15. Tamilnadu 2.03 644.72 646.75 

16. Tripura 13.18 13.18 

17. Uttar Pradesh 5.14 0.46 20.40 26.00 

18. Uttaranchal 0.11 0.11 

19. WBSEB -0.01 13.16 13.15 

20. DTL(DVB) 1310.83 8.80 0.18 1319.81 

21. 

Chattisgarh 

(CSEB) 

0.45 0.45 

22. Chandigarh 123.66 123.66 

23. Pondichery -1.59 -0.93 -2.52 

24. Jharkhand 1450.97 1450.97 

25. 

MEA (Power 

Nepal) 

6.03 6.03 

26. M/s NFL 0.01 0.01 

27. 

B.S.L. ProjS/ 

Nagar 

0.14 0.14 

28. 

Beas Project 

talwara 

0.03 0.03 

Total 1310.83 78.64 4.48 189.04 38.90 1467.86 974.29 10.86 172.24 42.87 4290.01 

(1/1) 

• 

Based on the information received from CPSUs up to 31-03-2009 


193


STATE-WISE ESTIMATED AVERAGE RATES OF ELECTRICITY 

Annexure-9B 

(Item No.9.2) 

(1/3) 

S. 

No. 

Name of 

Utility 

Tariff 

effective 

from 

Domestic 

1KW 

(100 

KWh/ 

Month) 

Domestic 

4KW 

(400 

KWh/ 

Month) 

Domestic 

10KW 

(1000 

KWh/ 

Month) 

Commercial 

2KW 

(300 

KWh/ 

Month) 

Commercial 

10KW 

(1500 

KWh/ 

Month) 

Commercial 

30KW 

(4500 

KWh/ 

Month) 

Commercial 

50KW 

(7500 

KWh/ 

Month) 

Agriculture 

2HP 

(400 

KWh/ 

Month) 

Agriculture 

5HP 

(1000 

KWh/ 

Month) 

Agriculture 

10HP 

(2000 

KWh/ 

Month) 

Small 

Industry 

10KW 

(1500 

KWh/ 

Month) 

Medium 

Industry 

50KW 

(7500 

KWh/ 

Month) 

Large 

Industry 

1000KW 

60%L.F. 

(438000 

KWh/ 

Month) 

Heavy 

Industry 

10000KW 

60%L.F. 

(4380000 

KWh/ 

Month) 

(Rates in Paise/KWh) 

1. Andhra 01-04-07 238.50 396.63 492.25 599.33 624.67 628.89 629.73 29.38 23.75 21.88 415.4 414.33 380.3 418.6 407.68 410.03 

Pradesh 

2. Assam 04-08-06 310.00 411.50 445.00 528.33 528.33 536.31 536.31 240.00 240.00 240.00 285.67U 450.33 370.2 369.07 358.05 

Heavy 

Industry 

(33KV) 

20000KW 

60%L.F. 

(8760000 

KWh/ 

Month) 

Railway Traction 

12500KW 

(25000000 

KWh/ Month) 

254R 

3. Bihar 01-11-06 233.20 U 294.05 362.52 515.87 503.85 500.09 499.33 51.50 R 51.50 R 51.50 R 490.38 525.72 497.84 484.56 531.89 at 25KV 

U 

76.32 R 51.94 R 61.50 U 61.50 U 61.50 U 525.89 at 

132KV 

4. Chhattisgarh 

01-11-07 198.80 239.53 357.93 457.08 489.74 489.31 488.85 32.50 32.50 111.25 304.52 413.35 423.47 423.47 452.4 477. 22 at 

132KV 

5. Gujarat 01-04-07 348.00 U 462.00 U 526.80 

U 

264.00 R 368.50 R 427.90 

R 

564.58 595.42 590.14 589.08 55.00 55.00 55.00 438.62 468.36 495 534.7 534.5 549.12 at 

132KV 

6. Haryana 01-11-06 356.20 410.05 450.82 468.00 468.00 468.00 468.00 17.50 17.50 17.50 478 499.9 457 457 445 481.29 at 11KV 

7. Himachal 01-04-07 216.00 263.50 283.00 450.67 437.33 448.44 447.56 208.00 205.00 204.00 386.33 406.56 340.12 325.99 323.6 

Pradesh 

8. Jammu & 01-04-07 129.50 188.88 214.75 222.00 262.00 268.67 270.00 49.50 40.33 27.50 222 222 256.09 256.09 250.2 

Kashmir 

9. Jharkhand 01-01-04 163.00 U 183.00 182.00 438.67 438.67 438.67 438.67 28.75 28.75 28.75 405.62 405.62 412.95 412.95 392.95 516.5 at 25KV 

10. Karnataka 01-11-06 292.43 D 418.30 D 482.32 

D 

292.43 E 413.05 E 473.92 

E 

260.93 F 381.55 F 442.42 

F 

74.00 R 477.69 at 

132KV 

637.88 

D 

618.63 

E 

609.87 

F 

651.18 

D 

630.53 

E 

623.18 

F 

653.39 

D 

632.51 

E 

625.39 

F 

653.84 

D 

632.91 

E 

625.83 F 

45.00 G 45.00 G 55.00 G 418.4D 521.47D 490.28D 501.07D 499.57D 485.88 

110.00 

H 

110.00 

H 

115.00 

H 

397.96O 477.57O 471.71D 482.5O 480.99O 

194 



(2/3) 

11. Kerala * 01-04-06 187.00 398.89 517.61 727.84 889.90 962.74 969.98 74.80 74.80 74.80 390.5 390.5 385.02D 385.02D 360.29 at 

110KV 

12. Madhya 

Pradesh 

16-04-08 347.44 U 454.13 U 475.31 U 565.83 567.17 567.39 567.43 188.75 213.50 221.75 385.62 540.4 480.83R 480.83R 468.01 460 at 

132/220KV 

341.74 R 430.38 R 451.05 R 348.8 478 

13. Maharashtra 

01-06-08 275.90 443.36 596.68 528.84 594.02 779.54 779.54 90.00 I 90.00 I 90.00 I 344.42 517.28 424.98B 424.98B - 410.85 

75.00 J 75.00 J 75.00 J 456.47O 456.47O 

14. Megha-laya 01-10-04 180.00 246.25 275.50 409.33 446.67 452.89 454.13 116.00 116.00 116.00 383.33 408.67 253.92 253.53 - - 

15. Orissa 01-04-08 135.20 247.00 286.00 384.80 443.04 452.75 454.69 102.00 102.00 102.00 322.4 335.81 361.51 361.46 361.46 413.48 at 

25/33KV 

16. Punjab 01-04-06 247.10 374.15 408.80 469.30 469.30 469.30 469.30 0.00 0.00 0.00 374.7 413.2 413.2 413.2 400.92 447 at 132KV 

17. Rajasthan 01-01-05 417.50 U 396.88 U 392.75 U 556.67 554.00 555.78 556.13 78.75 75.60 74.55 421.28 459.68 463.83 463.83 460.65 451 

390.25 R 363.81 R 358.53 R 

18. Tamil Nadu 01-04-07 120.00 216.25 269.50 602.00 607.60 608.53 608.72 0.00 0.00 0.00 458.85 486.57 452.11 462.61 452.11 526.47 

19. Uttar 

Pradesh 

20. Uttaranchal 

21. West 

Bengal 

22. Arunachal 

Pradesh 

10-05-07 249.00 U 359.00 U 359.00 U 452.33 U 452.33 U 452.33 

U 

59.00 R 209.00 R 239.00 R 209.00 R 269.00 R 279.00 

R 

01-04-06 215.00 215.00 215.00 315.00 

W 

365.00 

M 

315.00 

W 

365.00 

M 

315.00 

W 

365.00 

M 

01-04-07 248.33 U 406.43 U 529.24 U 443.27 U 583.96 U 604.05 

U 

237.11 R 391.49 R 523.26 R 441.48 R 583.59 R 603.93 

R 

452.33 U 224.00 U 224.00 U 224.00 

U 

452.33U 452.33U 404.18U 404.18U 418.29U 461.11 Below 

132KV 

281.00 R 45.00 R 45.00 R 45.00 R 385.83R 385.83R 344.91R 344.91R 356.9R 444.44 132KV 

and above 

315.00 

W 

81.60 U 78.00 U 76.80 U 305.09 305.09 282.1 282.1 275.68 

365.00 M 69.00 R 65.40 R 64.20 R 

608.07 147.00 147.00 147.00 379.78U 470.78U 470.81 470.81 447.14 453.79 at 25KV 

608.00 R 364.71R 450.2R 424.39 at 

132KV 

1-02-2000 162.50 211.88 231.75 370.00 390.00 393.33 394.00 - - - 345 353.33 393.86 394.89 - - 

23. Goa 01-04-02 143.00 188.00 233.00 386.33 413.67 429.89 433.13 120.50 119.00 118.50 257 297 342.29 342.29 342.29 - 

(2/2) 

24. Manipur 03-09-02 262.20 299.70 302.20 302.20 302.20 381.80 381.80 272.20 272.20 272.20 287.2 381.8 336.09 336.09 336.09 - 

25. Mizoram 

(Distt.HQ 

& sub. 

Divn. Area) 

Other 

Areas 

25-07-05 170.00 247.50 249.00 266.67 266.67 266.67 266.67 69.94 69.94 69.94 208.33 208.33 71.35 71.35 71.35 - 

180.00 195.00 198.00 

26. Nagaland 01-04-06 272.00 310.25 337.70 398.00 431.60 437.20 438.32 150.00 150.00 150.00 280 296.33 314.68 314.97 

27. Sikkim 01-04-06 105.75 266.06 322.43 335.25 396.45 408.15 410.49 180.00 247.50 326.25 414U 288.18 312.3 312.3 - - 

300R 


195


(3/3) 

28. Tripura 01-07-06 215.00 365.00 365.00 353.33 456.67 456.67 456.67 87.46 87.46 134.92 300 336.67 - - 

29. A & N 

Islands 

30. Chandigarh 

31. Dadra & 

Nagar 

Haveli 

32. Daman & 

Diu 

33. Delhi 

BYPL/ 

BRPL / 

NDPL 

34. Delhi 

NDMC 

35. Lakshadweep 

36. Puducherry 

37. Torrent 

Power Ltd. 

(Ahmedabad) 

38. Kolkata 

( CESC ) 

39. D.V.C. 

(A) Bihar 

Area 

(B) West 

Bengal 

Area 

40. Durgapur 

Projects 

Ltd. 

41. Mumbai 

( B.E.S.T ) 

Mumbai 

(Reliance 

Energy) 

Mumbai 

( TATA’S ) 

01-07-03 130.00 275.00 326.00 406.67 465.33 475.11 477.07 90.00 90.00 90.00 316.67 327.33 

01-08-05 179.00 304.00 304.00 347.00 347.00 347.00 347.00 165.00 165.00 165.00 350.33 387 360.7 360.7 350.21 - 

01-08-08 130.00 172.50 204.00 248.33 265.67 268.56 269.13 55.00 55.00 55.00 230 253.4 299.97 301 - - 

01-08-08 130.00 172.50 204.00 248.33 265.67 268.56 269.13 55.00 55.00 55.00 250 282.34 279.97 281 - - 

01-10-06 277.20 346.50 434.70 596.75 596.75 622.76 622.76 162.20 162.20 162.20 560 560 560.3 560.3 547.32 517.26 at 11KV 

01-04-06 158.00 252.25 327.70 462.00 525.00 525.00 525.00 - - - 431 431 - - - 576 

01-09-04 87.50 221.88 268.75 406.67 465.33 475.11 477.07 - - - 330 330 

16-04-02 55.00 113.75 150.50 274.73 325.35 333.78 335.47 0.00 20.67 19.83 247.52 257.5 320.15 332.72 - - 

01-04-07 345.15 399.26 427.64 527.88 586.51 592.79 594.54 311.64 311.64 311.64 396.73 446.4 411.62 411.62 - - 

01-04-07 279.84 462.48 533.62 450.53 579.26 597.30 600.91 - - - 393.17 485.04 442.18 442.18 411.25 373.38 

1-09-2000 - - - - - - - - - - - - 373.79 373.79 359.95 460.96 at 33KV 

- - - - - - - - - - - - 398.45 398.45 383.45 442.07 at 

132KV 

01-04-07 189.00 254.93 264.33 272.43 293.40 294.83 295.12 149.39 ^ 149.39 ^ 149.39 ^ 267.71 297.12 308.31 308.31 306.01 379.41 at 25KV 

374.41 at 132 

kV 

01-06-08 127.10 327.85 605.88 563.71 924.82 1301.97 1301.97 - - - 749.18 871.52 631.72 631.72 - - 

01-06-08 239.31 494.14 748.58 827.73 767.46 1173.32 1173.32 113.43 113.43 113.43 614.5 778.21 675.79 675.79 - - 

01-06-08 240.12 444.52 660.12 634.38 589.18 825.40 825.40 - - - 

581.58 785.55 625.42 625.42 470.57 

470.57 

32/22/11/6.6kV 

196 

“The farther backward you can look, the farther forward you are likely to see.”


S. 

No. 

RATE OF SALE OF POWER OF GENERATING STATIONS IN 

THE COUNTRY FOR THE YEAR 2007-08 

Name of the Utility/Power 

Station 

Energy 

Source- Coal/ 

Gas/ Naptha/ 

LSHS/ 

Diesel/ Hydro 


1 BHAKRA BEAS MANAGEMENT BOARD 

Bhakra Complex(Bhakra 

Hydro 

Plant.+Gang.+Kotla P. House) 

State where 

the unit is 

located 

Punjab/ 

H..P. 

Installed 

Capacity 

(MW) 

Net 

Generation 

(MkWh) 

Total 

cost of 

Generation 

(Rs. In 

Lakhs) 

Cost of 

Generation/ 

Unit (Paise/ 

(kWh) 

Total 

Energy 

Sold 

(MkWh) 

Annexure-9C 

(Item-9.5) 

Total 

Revenue 

Earned 

(Rs. In 

Lakhs) 

1478.73 6261.66 9554.64 15.26 N.A. 16062.59 £ 

Dehar Power House Hydro 990 2840.17 12619.10 44.43 N.A. 17.79 £ 

Pong Power Plant Hydro 396 1743.99 1408.45 8.08 N.A. 18.71 £ 

Total (BBMB) 10845.82 23582.19 21.74 N.A. 16099.09 £ 

2 DAMODAR VALLEY CORPORATION 

Bokaro T. P. S. Thermal-C Jharkhand 630 3376.73 59159.71 175.20 3292.09 106359.33 ψ 

Durgapur T. P. S. Thermal-C W.B. 350 1456.79 33136.74 227.46 1420.28 45885.60 ψ 

Chandrapura T.P.S. Thermal-C Jharkhand 750 2097.58 36357.58 173.33 2045.00 66068.89 ψ 

Mejia T. P. S. Thermal-C W.B. 840 5922.31 103989.14 175.59 5773.88 186539.51 ψ 

Gas Turbine Station Maithon Thermal-N Jharkhand 82.50 N.A. 816.48 N.A. N.A. N.A. ψ 

Sub Total Thermal (DVC) 12853.41 233459.65 181.63 12531.25 404853.33 ψ 

Maithon Hydel Station Hydro W.B. 60 202.68 1683.25 83.05 197.60 6383.75 ψ 

Panchet Hydel Station Hydro Jharkhand 80 208.72 1269.90 60.84 203.49 6574.12 ψ 

Tilaiya Hydel Power Station Hydro Jharkhand 4 20.40 469.60 230.22 19.88 642.18 ψ 

Sub Total Hydro (DVC) 431.79 3422.75 79.27 420.96 13600.05 ψ 

Total (DVC) 13285.20 237071.73 178.45 12952.21 418453.38 323 

3 NHPC LTD. 

Bairasiul Hydro H..P. 180 601.35 5711.00 94.97 522.41 5598.53 107 

Loktak Hydro Manipur 90 593.76 5474.00 92.19 518.98 5604.36 108 

Salal Hydro J. & K. 690 3225.28 9604.00 29.78 2817.03 21061.41 75 

Tanakpur Hydro Uttarakhand 94 435.24 5707.00 131.12 389.74 4809.13 123 

Chamera - I Hydro H..P. 540 2103.16 13532.00 64.34 1827.84 26972.09 148 

Uri Hydro J. & K. 480 2569.40 16745.00 65.17 2242.97 37486.83 167 

Rangit Hydro Sikkim 60 328.38 3711.00 113.01 285.29 4986.51 175 

Chamera - II Hydro H..P. 300 1404.03 24975.00 177.88 1222.93 37868.14 310 

Dhauliganga Hydro Uttarakhand 280 1176.81 23305.00 198.04 1025.66 19662.66 192 

Dulhasti Hydro J. & K. 390 2165.11 51436.00 237.57 1886.01 55910.53 296 

Total (NHPC) 14602.52 160200.00 109.71 12738.86 219960.18 173 

(1/15) 

Rate of 

Sale of 

Power/ 

Unit 

(Paise/ 

Kwh) 


197


4 NATIONAL THERMAL POWERCORPORATION LIMITED § 

Singrauli Thermal-C U..P. 2000 N.A. N.A. N.A. 14984.00 172614.00 115 

Korba Thermal-C Chhatisgarh 2100 N.A. N.A. N.A. 16656.00 155229.00 93 

Ramagundam Thermal-C A.P. 2600 N.A. N.A. N.A. 19316.00 300786.00 156 

Farakka Thermal-C W.B. 1600 N.A. N.A. N.A. 10939.00 206836.00 189 

Vindhyachal Thermal-C M.P. 2760 N.A. N.A. N.A. 23757.00 366355.00 154 

Rihand Thermal-C U..P. 2000 N.A. N.A. N.A. 15658.00 243246.00 155 

FGUTPS-Unchahar Thermal-C U..P. 1050 N.A. N.A. N.A. 8285.00 165932.00 20 

NCTPS-Dadri coal Thermal-C U..P. 840 N.A. N.A. N.A. 6707.00 157033.00 234 

Kahalgaon Thermal-C Bihar 840 N.A. N.A. N.A. 6138.00 126021.00 205 

Talcher Thermal-C Orissa 3000 N.A. N.A. N.A. 23470.00 296944.00 127 

Talcher TPS Thermal-C Orissa 460 N.A. N.A. N.A. 3135.00 40817.00 130 

Tanda Thermal-C U..P. 440 N.A. N.A. N.A. 3149.00 65613.00 208 

Simhadri Thermal-C A.P. 1000 N.A. N.A. N.A. 7324.00 142272.00 194 

Anta Thermal-G Rajasthan 419 N.A. N.A. N.A. 2676.00 70719.00 264 

Auraiya Thermal-G U..P. 663 N.A. N.A. N.A. 3978.00 103281.00 260 

Dadri Thermal-G U..P. 830 N.A. N.A. N.A. 5100.00 162143.00 318 

Kawas Thermal-G Gujarat 656 N.A. N.A. N.A. 3609.00 208597.00 578 

Gandhar Thermal-G Gujarat 657 N.A. N.A. N.A. 3918.00 133561.00 341 

Rajiv Gandhi (Kayamkulam) Thermal-N Kerala 360 N.A. N.A. N.A. 1681.00 138708.00 825 

Faridabad Thermal-G Haryana 432 N.A. N.A. N.A. 2579.00 79565.00 308 

Badarpur Thermal-C Delhi 705 N.A. N.A. N.A. 4930.00 130741.00 265 

Total (NTPC) N.A. N.A. N.A. 187989.00 3467013.00 184 

5 NEYVELI LIGNITE CORPORATION LTD. 

Thermal Station I Expansion Thermal-Lig T.N. 420 2994.06 48833.05 163.10 2974.57 61129.26 206 

Thermal Station II Thermal-Lig T.N. 1470 9486.88 140709.45 148.32 8713.86 134688.95 155 

Thermal Station I Thermal-Lig T.N. 600 3235.03 54626.73 168.86 2916.10 51481.60 177 

Total (NLL) 15715.97 244169.23 155.36 14604.53 247299.81 169 

6 NORTH EASTERN ELECTRIC POWER CORP. LTD. 

Kopili+Khandong+Kopili 

Stage-II HEP 

Hydro Assam 275 1123.59 6416.19 570.00 1123.59 8847.30 790 

Ranganadi HEP (RHEP) Hydro Ar. Pradesh 405 1351.11 11742.78 870.00 1351.11 26005.34 192 

Doyang HEP (DHEP) Hydro Nagaland 75 230.99 4445.29 192.00 230.99 6138.23 266 

Sub Total Hydro (NEEPCO) 2705.69 22604.26 83.54 2705.69 40990.87 151 

Assam Gas Based Power Plant 

(AGBPP) 

Thermal-G Assam 291 1692.32 32167.35 190.00 1692.32 32965.11 195 

Agartala Gas Turbine Plant Thermal-G Tripura 84 647.79 10876.16 168.00 647.79 12075.01 186 

Sub Total Thermal (NEEPCO) 2340.11 43043.51 183.94 2340.11 45040.12 192 

Total (NEEPCO) 5045.80 65647.77 130.10 5045.80 86030.99 171 

7 SATLUJ JAL VIDYUT NIGAM LTD. 

Nathpa Jhakri Hydro Power Stn Hydro H..P. 1500 6385.34 60875.71 95.00 5564.72 135462.28 243 

8 TEHRI HYDRO DEVELOPMENT CORPORATION 

Tehri HPP Stage -I Hydro Uttarakhand 1000 2566.12 64203.02 250.20 2251.66 111099.49 493 

(2/15) 

198 



9 NARMADA HYDROELECTRIC DEV. COR. LTD. 

Indira Sagar Project Hydro M.P. 1000 2729.84 10493.55 38.44 2714.73 54877.41 202 

Omkareshwar Project Hydro M.P. 520 702.04 5147.15 73.32 686.94 14928.55 217 

Total (NARMADA HYDROELECTRIC DEV. COR. LTD.) 3431.88 15640.70 45.57 3401.67 69805.96 205 

10 NUCLEAR POWER CORPORATION OF INDIA 

TAPS 1 TO 4 Nuclear Maharashtra 1400 7339.44 145329.80 198.01 6466.60 136699.69 211 

Rajasthan (Unit-2, 3 & 4) Nuclear Rajasthan 640 2661.91 61317.59 230.35 2208.57 63108.02 286 

Madras (Unit-1 & 2) Nuclear T.N. 440 1751.00 27665.27 158.00 1518.00 27989.38 184 

Narora (Unit-1 & 2) Nuclear U..P. 440 673.97 15787.87 234.25 530.97 9233.01 174 

Kakrapar (Unit-1 & 2) Nuclear Gujarat 440 2029.89 32949.12 162.32 1728.47 34828.69 202 

Kaiga (Unit-1, 2 & 3) Nuclear Karnataka 660 2507.81 69565.31 277.39 2151.56 60859.15 283 

Total (Nuclear Power Corporation of India) 16964.02 352614.96 207.86 14604.17 332717.94 228 

NORTHERN REGION 

1 HARYANA POWER GENERAL CORPORATION LTD. 

Panipat T. P. S. (4x110) Thermal-C Haryana 440 2015.72 65763.95 326.26 2014.88 58320.22 289 



Faridabad T. P. S. Thermal-C Haryana 165 608.00 32618.87 536.49 607.33 26219.59 432 

Sub Total Thermal(Haryana Power General Corporation Ltd.) 9521.75 275225.64 289.05 9514.77 275707.15 290 

Western Yamuna Canal H. E. P. Hydro Haryana 62.40 268.10 3377.00 125.96 268.10 3002.69 112 

Kakroi Hydel Project Hydro-Mic Haryana 0.30 0.19 49.50 2639.85 0.19 2.10 112 

Sub Total Hydro(Haryana Power General Corporation Ltd.) 268.29 3426.50 127.72 268.29 3004.79 112 

Total (Haryanna Power General Corporation Ltd.) 9790.04 278652.14 284.63 9783.06 278711.94 285 

2 HIMACHAL PRADESH STATE ELECTRICITY BOARD 

Giri Power House Hydro H..P. 60 176.17 852.00 48.00 N.A. N.A. ψ 

Andhra Power House Hydro H..P. 16.95 65.73 421.00 64.00 N.A. N.A. ψ 

Gumma Power House Hydro H..P. 3 7.86 228.00 291.00 N.A. N.A. ψ 

Bhaba P H /Sanja P H Hydro H..P. 120 450.37 1809.00 40.00 N.A. N.A. ψ 

Nogil Power House Hydro H..P. 2.05 10.53 151.00 143.00 N.A. N.A. ψ 

Ghanvi Power House Hydro H..P. 22.50 77.63 994.00 128.00 N.A. N.A. ψ 

Bassi Power House Hydro H..P. 60 284.37 801.00 28.00 N.A. N.A. ψ 

Binwa Power House Hydro H..P. 6 31.95 320.00 100.00 N.A. N.A. ψ 

Gaj Power House Hydro H..P. 10.50 45.93 503.00 110.00 N.A. N.A. ψ 

Baner Power House Hydro H..P. 12 43.06 494.00 115.00 N.A. N.A. ψ 

Chaba Power House Hydro H..P. 1.75 6.13 90.00 147.00 N.A. N.A. ψ 

Rukti Power House Hydro H..P. 1.50 1.74 48.00 275.00 N.A. N.A. ψ 

Rongtong Power House Hydro H..P. 2 1.60 94.00 586.00 N.A. N.A. ψ 

Chaba Power House Hydro H..P. 0.45 0.38 16.00 420.00 N.A. N.A. ψ 

Sal-II Power House Hydro H..P. 2 5.48 83.00 151.00 N.A. N.A. ψ 

Killar Power House Hydro H..P. 0.30 0.90 42.00 461.00 N.A. N.A. ψ 

Holi Power House Hydro H..P. 3 10.79 100.00 92.00 N.A. N.A. ψ 

Thirot Power House Hydro H..P. 4.50 8.54 245.00 287.00 N.A. N.A. ψ 

Khauli Power House Hydro H..P. 12 44.78 1183.00 264.00 N.A. N.A. ψ 

Larji Power House Hydro H..P. 126 585.05 12635.00 216.00 N.A. N.A. ψ 

Total (Himachal Pradesh State Electricity Board) 1859.01 21109.00 113.55 6217.06 221906.04 357 

(3/15) 


199


3 INDRAPRASTHA POWER GENERAL CORPORATION LTD. 

Rajghat Power House Thermal-C Delhi 135 780.27 22854.34 292.90 780.2709 21500.66 276 

Indraprastha Power Station Thermal-C Delhi 247.50 606.63 20885.06 344.28 606.6258 20008.98 330 

I. P. Gas Turbine Power Station Thermal-G Delhi 282 1241.15 32115.97 258.76 1241.1521 31708.01 255 

Total (I. P. Power Gen.Co. Ltd.) 2628.05 75855.37 288.64 2628.05 73217.65 279 

4 PRAGATI POWER CORP. LTD. 

Pragati Power Station Thermal-G Delhi 330 2303.48 34678.21 150.55 2303.48 42494.01 184 

5 JAMMU & KASHMIR, POWER DEVELOPMENT DEPT. 

Pampore Thermal-G J & K 175 N.A. N.A. N.A. N.A. N.A. N.A. 

Sub Total Thermal (J & K) 

Lower Jhelum Hydro J & K 105 N.A. N.A. N.A. N.A. N.A. N.A. 

Upper Sindh Hydro J & K 127 N.A. N.A. N.A. N.A. N.A. N.A. 

Gandharwal Hydro J & K 15 N.A. N.A. N.A. N.A. N.A. N.A. 

Chenani Hydro J & K 32.80 N.A. N.A. N.A. N.A. N.A. N.A. 

Mohara Hydro J & K 9 N.A. N.A. N.A. N.A. N.A. N.A. 

Kargil Hydro J & K 3.75 N.A. N.A. N.A. N.A. N.A. N.A. 

Sewa Hydro J & K 9 N.A. N.A. N.A. N.A. N.A. N.A. 

Steknan Hydro J & K 4 N.A. N.A. N.A. N.A. N.A. N.A. 

Sub Total Hydro (J & K) 

Total (Jammu & Kashmir) 

6 PUNJAB STATE ELECTRICITY BOARD 

G.N.D.T.P. Bathinda Thermal-C Punjab 440 2663.27 63849.53 239.74 N.A. N.A. ψ 

G.G.S.S.T.P Ropar Thermal-C Punjab 1260 8977.60 191503.31 213.31 N.A. N.A. ψ 

G.H.T.P Lehra Mohabat Thermal-C Punjab 420 3317.03 69380.48 209.16 N.A. N.A. ψ 

Sub Total Thermal (P S E B) 14957.90 324733.32 217.10 N.A. N.A. ψ 

Shan HEP (UHL) Hydro H.P. 110 533.58 1430.86 26.82 N.A. N.A. ψ 

U.B.D.C.Pathankot Hydro Punjab 91.35 422.63 2715.29 64.25 N.A. N.A. ψ 

Anandpur Sahib Hydro Punjab 134 704.02 3268.46 46.43 N.A. N.A. ψ 

Mukerian Hydel Hydro Punjab 207 1328.44 5525.40 41.59 N.A. N.A. ψ 

Micro Hydel (Nidampur+ 

Dodhar+Thuhi+Rohti) 

Hydro Punjab 4.90 7.00 106.46 152.08 N.A. N.A. ψ 

Ranjit Sagar Dam (R.S.D). Hydro Punjab 600 1532.64 50214.17 327.63 N.A. N.A. ψ 

L. Bank & R. Bank Hydro Punjab 684 2474.49 4733.95 19.13 N.A. N.A. ψ 

Beas & Extn. Hydro H.P. 573 1681.13 8062.03 47.96 N.A. N.A. ψ 

Sub Total Hydro (P. S. E. B.) 8683.93 76056.62 87.58 N.A. N.A. ψ 

Total (P. S. E. B.) 23641.83 400789.94 169.53 31819.33 791313.56 249 

7 RAJASTHAN RAJYA VIDYUT UTPADAN N. Ltd. 

Kota STPS Thermal-C Rajasthan 1045 8382.58 14708.33 175.00 7596.99 145350.45 191 

Suratgarh STPS Thermal-C Rajasthan 1250 10207.51 261694.79 256.37 9268.73 242610.70 262 

Ramgarh Gas TPS Thermal-G Rajasthan 110.50 379.72 9628.37 253.56 358.95 11418.46 318 

Dholpur Gas TPS Thermal-G Rajasthan 330 214.88 6317.58 294.00 210.01 6113.68 291 

Sub Total Thermal (Rajasthan R. V. U. N. Ltd.) 19184.69 292349.07 152.39 17434.69 405493.29 233 

Mahi Hydel Power Station Hydro Rajasthan 140 282.81 529.36 187.17 280.72 871.31 310 

Mini Micro Hydel Power Stn. Hydro Rajasthan 23.85 12.68 480.41 378.88 12.43 313.32 252 

Rana Pratap Sagar Power Stn. Hydro Rajasthan 172 676.04 720.44 10.65 676.04 720.44 11 

Jawahar Sagar Power Stn. Hydro Rajasthan 99 431.88 511.30 11.83 431.88 511.30 12 

Sub Total Hydro (Rajasthan Rajya V. U. N. Ltd.) 1403.40 2241.51 15.97 1401.06 2416.37 17 

Total (Rajasthan Rajya V. U. N. Ltd.) 20588.10 294590.58 143.09 18835.75 407909.65 217 

(4/15) 

200 

“The farther backward you can look, the farther forward you are likely to see.”


(5/15) 

8 UTTARAKHAND JAL VIDYUT NIGAM LIMITED 

Maneri Bhali-II Hydro Uttarakhand 304 31.53 269.00 31.40 844.66 269 

Chibro Hydro Uttarakhand 240 755.69 2530.00 34.03 743.19 1964.68 26 

Ramganga Hydro Uttarakhand 264 279.06 1421.00 46.00 270.50 1244.32 46 

Chilla Hydro Uttarakhand 204 825.98 2418.00 36.27 819.55 2972.51 36 

Khodri Hydro Uttarakhand 120 354.72 1638.00 47.81 349.00 1283.26 39 

Tiloth Hydro Uttarakhand 90 466.14 2417.00 61.62 451.46 2781.88 62 

Dhalipur Hydro Uttarakhand 51 210.70 880.00 46.16 207.32 736.68 36 

Khatima Hydro Uttarakhand 41.40 155.34 675.00 35.02 151.36 530.05 35 

Dhakrani Hydro Uttarakhand 33.75 148.92 596.00 38.25 129.68 369.31 28 

Kulhal Hydro Uttarakhand 30 149.76 589.00 38.55 145.46 456.62 31 

Total (Uttaranchal Jal Vidyut Nigam Limited) 3377.84 13164.00 38.97 3298.92 13183.97 40 

9 U. P. JAL VIDYUT NIGAM LIMITED 

Pipri Hydro U..P. 300 406.80 1576.21 38.75 383.18 1936.00 51 

Obra Hydro U..P. 99 167.90 780.02 46.46 165.67 902.00 54 

Matatila/Sheetla Hydro U..P. 33.60 67.23 204.11 30.36 66.88 489.00 73 

Muzaffar Nagar Hydro U..P. 15.50 22.74 243.01 106.86 22.53 447.00 198 

Khara/Eyc Hydro U..P. 78 256.33 3098.43 120.88 252.28 2909.00 116 

Total ( U. P. JAL VIDYUT NIGAM LIMITED) 921.00 5901.78 64.08 890.54 6683.00 75 

10 UTTAR PRADESH R. V. U. N. LTD. 

Anpara A Thermal-C U..P. 630 3626.24 54464.10 150.19 3524.21 46186.50 131 

Anpara B Thermal-C U..P. 1000 6875.75 113591.40 165.21 6801.64 117262.20 172 

Obra A Thermal-C U..P. 442 645.87 20894.20 323.50 543.83 10747.90 198 

Obra B Thermal-C U..P. 1000 4028.89 77153.00 191.50 3990.23 56301.30 141 

Panki Thermal-C U..P. 210 924.23 30535.30 330.39 909.24 21520.40 237 

Harduganj B & C Thermal-C U..P. 275 640.20 29757.20 484.81 638.80 18955.90 297 

Paricha Thermal-C U..P. 220 539.83 25410.40 470.71 539.48 14145.90 262 

Paricha Ext. Unit No. 3 Thermal-C U..P. 250 1150.74 38245.90 332.38 1144.23 31461.40 275 

Paricha Ext. Unit No. 4 Thermal-C U..P. 250 517.89 13566.80 261.96 364.85 10736.00 294 

Total (UTTAR PRA. R. V. U. N. LTD) 18949.64 403618.30 213.00 18456.51 327317.50 177 

WESTERN REGION 

1 CHHATTISGARH STATE ELECY. BOARD 

Korba-East Thermal-C Chhattisgarh 440 3203.65 32677.23 102.00 N.A. N.A. ψ 

Korba-East-STV Thermal-C Chhattisgarh 500 774.74 8057.30 104.00 N.A. N.A. ψ 

Korba-West Thermal-C Chhattisgarh 840 6086.37 52951.42 87.28 N.A. N.A. ψ 

Sub Total Thermal(Chhatisgarh S. E. Board) 10064.76 93685.95 93.08 N.A. N.A. ψ 

HEP Machadoli Bango Hydro Chhattisgarh 120 221.51 1116.40 50.40 N.A. N.A. ψ 

HEP-Gangrel Hydro Chhattisgarh 10 33.84 189.53 56.00 N.A. N.A. ψ 

HEP Sikasar Hydro Chhattisgarh 70 9.52 58.09 61.00 N.A. N.A. ψ 

Sub Total Hydro (Chhatisgarh S. E. Board) 264.87 1364.02 51.50 N.A. N.A. ψ 

Total (Chhatisgarh S. E. Board) 10329.64 95049.97 92.02 10814.04 327959.66 303 


201


2 GUJARAT STATE ELECTRICITY CORPORATION LTD. 

Ukai TPS Thermal-C Gujarat 850 4589.78 88062.88 192.00 4589.80 85144.31 186 

Gandhinagar TPS (Unit-1-4) Thermal-C Gujarat 660 3432.02 91191.50 266.00 3394.23 88701.16 261 

Gandhinagar 5 Thermal-C Gujarat 210 1590.56 32435.13 204.00 1591.55 36470.18 229 

Wanakbori TPS Thermal-C Gujarat 1260 8396.51 179269.65 214.00 8452.71 174944.67 207 

Wanakbori TPS 7 Thermal-C Gujarat 210 1635.29 30577.54 187.00 1664.89 36494.92 219 

Sikka TPS Thermal-C Gujarat 240 1332.19 39691.82 298.00 1326.14 40535.24 306 

Kutch Lignite TPS Thermal-C Gujarat 215 1200.14 26114.72 218.00 1192.20 28500.77 239 

Dhuvaran Thermal-L Gujarat 220 1217.11 50963.94 419.00 1234.19 60325.39 489 

Dhuvaran CCPP-1 Thermal-G Gujarat 107 671.89 23882.89 355.00 673.90 24364.71 362 

Dhuvaran CCPP-2 Thermal-G Gujarat 112 390.55 19202.57 492.00 390.78 18709.02 479 

Utran GBPS (GT-1 to 3 & STG) Thermal-G Gujarat 135 945.41 23741.97 251.00 941.45 23497.79 250 

Sub Total Thermal (Gujarat State Elecy. Corp. Ltd.) 25401.45 605134.61 238.23 25451.84 617688.16 243 

Ukai Hydro & Ukai Hydro- 

LBC 

Hydro Gujarat 305 930.33 2100.47 23.00 925.53 2659.00 29 

Kadana & Panam Hydro Hydro Gujarat 242 300.17 4948.23 165.00 291.72 7216.21 247 

Sub Total Hydro (Gujarat State Elecy. Corp. Ltd.) 1230.50 7048.70 57.28 1217.25 9875.21 81 

Total (Gujarat State Elecy. Corp. Ltd.) 26631.95 612183.31 229.87 26669.09 627563.37 235 

3 M.P.P.G.C.L., JABALPUR 

Amarkantak,Chachai 

TPH(PhI&II) 

Thermal-C M.P. 290 967.20 16240.25 167.91 967.20 15481.77 160 

Satpura TPH Sarni (PH I,II 

& III) 

Thermal-C M.P. 1142.50 6165.22 101312.07 164.33 6165.22 103074.63 167 

Sanjay Gandhi TPH 

Birsinghpur (PH I & II) 

Thermal-C M.P. 840 4648.12 77705.85 167.18 4648.12 75235.47 162 

Sub Total Thermal (M.P.P.G.C.L., JABALPUR) 11780.54 195258.17 165.75 11780.54 193791.87 165 

Rani Avanti Bai HPS Bargi Hydro M.P. 90 428.27 969.00 22.63 428.27 1025.33 24 

Pench HPS Totladoh,Nagpur Hydro M.P. 160 281.46 895.33 31.81 281.46 1333.49 47 

Gandhi Sagar HPS, Mandsour Hydro M.P. 115 250.93 558.50 22.26 250.93 807.53 32 

Tons (Tons+Bansagar 

II+Bansagar III) 

Hydro M.P. 405 1237.73 9292.00 75.07 1237.73 10220.53 83 

Rajghat HPS Hydro M.P. 45 25.12 672.18 267.56 25.12 735.99 293 

Sanjay Gandhi HPS, 

Birsinghpur 

Hydro M.P. 20 34.28 392.60 114.52 34.28 432.74 126 

Madhikhera HPS Hydro M.P. 60 10.21 2555.00 2501.43 10.21 2881.41 2822 

Jhinna HPS, Jhinna Hydro M.P. 20 16.96 1694.00 998.73 16.96 1892.86 1116 

Sub Total Hydro (M.P.P.G.C.L., JABALPUR) 2284.96 17028.61 74.52 2284.96 19329.88 85 

Total (M.P.P.G.C.L., JABALPUR) 14065.50 212286.78 150.93 14065.50 213121.75 152 

4 MAHARASHTRA STATE POWER GENERATION CORPORATION LTD. 

Chandrapur Thermal-C Maharashtra 2340 14697.10 207464.60 141.16 14697.10 247403.31 168 

Koradi Thermal-C Maharashtra 1100 5701.28 99124.14 173.86 5701.28 90929.42 159 

Khaperkheda Thermal-C Maharashtra 840 5733.55 96758.38 168.76 5733.55 103441.47 180 

Bhusawal Thermal-C Maharashtra 482.50 2857.54 65060.76 227.68 2857.54 60066.18 210 

Nasik Thermal-C Maharashtra 910 5723.29 131419.49 229.62 5723.29 119805.61 209 

Parali Thermal-C Maharashtra 690 4383.39 98537.71 224.80 4383.39 97990.46 224 

(6/15) 

202 

“The one exclusive sign of thorough knowledge is the power of teaching.”


Paras Thermal-C Maharashtra 62.50 300.92 7935.55 263.71 300.92 6022.31 200 

Uran GT Thermal-G Maharashtra 672 3648.75 38875.41 106.54 3648.75 54680.99 150 

WHR Thermal-G Maharashtra 240 N.A. N.A. N.A. N.A. N.A. 

Sub Total Thermal (MAHAGENCO ) 43045.83 745176.04 173.11 43045.83 780339.75 181 

Koyna Hydro Maharashtra 1920 3579.06 16300.26 45.54 3579.06 20079.14 56 

Small Hydro(Bhira, Vaitaran, 

Tillari Hydro Power Stations) 

Hydro Maharashtra 200 997.90 431.66 4.33 997.90 3642.77 37 

Sub Total Hydro (MAHAGENCO) 4576.97 16731.92 36.56 4576.97 23721.91 52 

Total (MAHAGENCO ) 47622.80 761907.96 159.99 47622.80 804061.66 169 

5 SARDAR SAROVAR NARMADA NIGAM LTD. 

Sardar Sarovar Project Hydro Gujarat 1450 44354.69 43443.00 97.94 697.30 14294.54 205 

SOUTHERN REGION 

1 ANDHRA PRADESH GAS POWER CORPORATION LTD. 

Gas Turbo Power Station St- I Thermal-G A.P. 100 5991.19 9160.79 152.90 5991.19 9198.57 141 

Gas Turbo Power Station St- II Thermal-G A.P. 172 5145.24 8385.25 163.00 5145.24 6947.02 135 

Total (Andhra Pradesh Gas Power Corp. Ltd.) 11136.43 17546.04 157.56 11136.43 16145.59 145 

2 ANDHRA PRADESH POWER GENERATION CORPORATION LTD. $ 

Vijaywada TPS Thermal-C A.P. 1260 8869.95 128135.30 144.46 N.A. N.A. ψ 

Rayalaseema TPS -I Thermal-C A.P. 210 2808.83 57825.38 205.87 N.A. N.A. ψ 

Rayalaseema TPP -I I Thermal-C A.P. 210 1140.45 24977.00 219.01 N.A. N.A. ψ 

Kothagudem TPS O & M Thermal-C A.P. 500 4595.33 62634.35 136.30 N.A. N.A. ψ 

Kothagudem TPS (KTPS-V) Thermal-C A.P. 720 3590.31 50688.00 141.18 N.A. N.A. ψ 

Ramagundem TPS Thermal-C A.P. 62.50 452.02 7034.34 155.62 N.A. N.A. ψ 

Sub Total Thermal(A. P. Power Gen. Corp. Ltd.) 21456.89 331294.36 154.40 N.A. N.A. ψ 

Srisailam (O&M) Hydro A.P. 770 2178.09 5663.03 26.00 N.A. N.A. ψ 

Srisailam LB(SLBHES) Hydro A.P. 900 2539.54 13713.52 54.00 N.A. N.A. ψ 

N’ Sagar Hydro A.P. 965 2423.80 5817.12 24.00 N.A. N.A. ψ 

Upper Sileru Hydro A.P. 240 521.99 2087.96 40.00 N.A. N.A. ψ 

Lower Sileru Hydro A.P. 460 1254.93 2384.37 19.00 N.A. N.A. ψ 

Donkarayi Hydro A.P. 25 132.90 863.85 65.00 N.A. N.A. ψ 

Penna Ahobilar (PABRHES) Hydro A.P. 20 2.16 294.07 1361.45 N.A. N.A. ψ 

Pochampad Hydro A.P. 27 63.72 386.84 60.71 N.A. N.A. ψ 

Singur Hydro A.P. 15 2.42 320.89 1326.00 N.A. N.A. ψ 

Nizamsagar Hydro A.P. 5 8.01 100.98 126.07 N.A. N.A. ψ 

Peddapalli Hydro A.P. 9.16 7.71 295.29 383.00 N.A. N.A. ψ 

Chettipeta Hydro A.P. 1 3.90 40.14 102.92 N.A. N.A. ψ 

Palair Hydro A.P. 2 2.64 73.85 279.73 N.A. N.A. ψ 

Machkund Hydro A.P. 84 238.77 1029.34 43.11 N.A. N.A. ψ 

Tungbadra Dam (AP Share) Hydro A.P. 72 185.24 707.43 38.19 N.A. N.A. ψ 

Sub Total Hydro (A. P. Power Gen.Corp. Ltd.) 9565.82 33778.69 35.31 N.A. N.A. ψ 

Total (A. P. Power Gen.Corp. 

Ltd.) 

Th/Hy A.P. 31022.71 365073.04 137.77 31022.63 519554.89 167 

3 KARNATAKA POWER CORPORATION LTD. 

Sharavathy ( U 1-10) Hydro Karnataka 1035 5764.51 7676.46 13.32 5764.51 8662.10 15 

Linganamakki ( U 1-2) Hydro Karnataka 55 325.61 2772.16 85.14 325.61 689.64 21 

(7/15) 


203


Bhadra RT Bank ( U 1-2) Hydro Karnataka 13.20 11.95 445.94 373.19 11.95 205.35 172 

Bhadra LT Bank ( U 1) Hydro Karnataka 2 53.06 1318.83 248.54 53.06 66.43 13 

Gerusoppa Power House 

( U 1-4) 

Hydro Karnataka 240 630.00 7509.91 119.20 630.00 17199.08 273 

Mahatma Gandhi HE, Jogfalls 

( U 1-8) 

Hydro Karnataka 139.20 298.48 1491.38 49.97 298.48 3096.28 104 

Almatti Dam PH ( U 1-6) Hydro Karnataka 290 655.63 5377.43 82.02 655.63 9614.69 147 

Munirabad ( U 1-3) Hydro Karnataka 28 105.60 573.46 54.31 105.60 668.84 63 

Kadra ( U 1-3) Hydro Karnataka 150 409.54 6421.50 156.80 409.54 6168.07 151 

Kodasalli ( U 1-3) Hydro Karnataka 120 385.58 4825.34 125.15 385.58 4729.89 123 

Nagjhari ( U 1-6) Hydro Karnataka 855 3229.46 11439.83 35.42 3229.46 11496.89 36 

Supa ( U 1-2) Hydro Karnataka 100 522.54 1337.99 25.61 522.54 1860.18 36 

Ghataprabha ( U 1-2) Hydro Karnataka 32 114.99 557.37 48.47 114.99 783.99 68 

Varahi ( U 1-2) Hydro Karnataka 230 1365.71 8101.20 59.32 1365.71 7647.90 56 

Mani Dam Power House 

( U 1-2) 

Hydro Karnataka 9 41.24 317.00 76.86 41.24 214.47 52 

Sivasamundrum ( U 1-10) Hydro Karnataka 42 290.14 1595.23 54.98 290.14 2849.50 98 

Shimshapura ( U 1-2) Hydro Karnataka 17.20 59.14 653.29 110.47 59.14 215.32 36 

Mini Hydel Hydro Karnataka 1.79 16.29 384.90 236.31 16.29 188.88 116 

Sub Total Hydro (Karnataka Power Corp. Ltd.) 14279.47 62799.22 43.98 14279.47 76357.50 53 

Raichur T.P.S. St-I & II 

( U 1-7) 

Thermal-C Karnataka 1470 9969.47 216559.15 217.22 9969.47 239640.44 240 

D G Plant Yelahanka 

( U 1-6) 

Thermal-DG Karnataka 127.92 206.75 15183.05 734.37 206.75 16231.57 785 

Sub Total Thermal (Karnataka Power Corp. Ltd.) 10176.22 231742.20 227.73 10176.22 255872.01 251 

Total (Karnataka Power Corp. Ltd.) 24455.69 294541.42 120.44 24455.69 332229.51 136 

4 KERALA STATE ELECTRICITY BOARD 

Pallivasal Hydro Kerala 37.50 229.04 N.A. N.A. N.A. N.A. ψ 

Sengulam Hydro Kerala 48 164.77 N.A. N.A. N.A. N.A. ψ 

Poringal Hydro Kerala 32 162.59 N.A. N.A. N.A. N.A. ψ 

Narimangalam Hydro Kerala 54 313.06 N.A. N.A. N.A. N.A. ψ 

Panniyar Hydro Kerala 30 82.15 N.A. N.A. N.A. N.A. ψ 

Sabarigiri Hydro Kerala 320 1541.35 N.A. N.A. N.A. N.A. ψ 

Sholayar Hydro Kerala 54 254.68 N.A. N.A. N.A. N.A. ψ 

Kuttiyadi & Kuttiyadi Extn Sch. Hydro Kerala 125 646.02 N.A. N.A. N.A. N.A. ψ 

Idukki Hydro Kerala 780 3316.02 N.A. N.A. N.A. N.A. ψ 

Idamalayar Hydro Kerala 75 474.63 N.A. N.A. N.A. N.A. ψ 

Kallada Hydro Kerala 15 73.03 N.A. N.A. N.A. N.A. ψ 

Peppara Hydro Kerala 3 8.18 N.A. N.A. N.A. N.A. ψ 

Lower Periyar Hydro Kerala 180 677.97 N.A. N.A. N.A. N.A. ψ 

Madupetty Hydro Kerala 2 6.91 N.A. N.A. N.A. N.A. ψ 

Poringal Left Bank Extn. Hydro Kerala 16 59.94 N.A. N.A. N.A. N.A. ψ 

Kakkad Hydro Kerala 50 246.75 N.A. N.A. N.A. N.A. ψ 

Malampuzha Shep Hydro Kerala 2.50 0.00 N.A. N.A. N.A. N.A. ψ 

Chembukadavu I & II Hydro Kerala 6.45 9.28 N.A. N.A. N.A. N.A. ψ 

Urumi I & II Hydro Kerala 6.15 13.77 N.A. N.A. N.A. N.A. ψ 

Malankara Hydro Kerala 10.50 43.70 N.A. N.A. N.A. N.A. ψ 

Lower Meenmutty Hydro Kerala 3.50 4.92 N.A. N.A. N.A. N.A. ψ 

Sub Total Hydro (Kerala State Elecy. Board) 8328.75 6791.73 8.16 N.A. N.A. ψ 

(8/15) 

204 



Kozhikode Diesel Power Plant Thermal-C Kerala 128 278.38 N.A. N.A. N.A. N.A. ψ 

(9/15) 

Brahmapuram Diesel Power 

Plant 

Thermal-C Kerala 106.60 95.76 N.A. N.A. N.A. N.A. ψ 

Sub Total Thermal (Kerala S. E. Board) 374.14 28268.43 755.56 N.A. N.A. ψ 

Total (Kerala SEB) Th+Hy Kerala 8702.89 35060.16 40.28 13397.00 469695.48 351 

5 LAKSHADWEEP, DEPARTMENT OF ELECTRICITY 

Miniocy Thermal-DG Lakshadweep 1.75 5.75 N.A. N.A. 5.03 N.A. ψ 

Kavaratti Thermal-DG Lakshadweep 1.80 6.02 N.A. N.A. 5.12 N.A. ψ 

Amini Thermal-DG Lakshadweep 2.18 2.43 N.A. N.A. 2.08 N.A. ψ 

Andrott Thermal-DG Lakshadweep 3.00 4.41 N.A. N.A. 3.66 N.A. ψ 

Kalpeni Thermal-DG Lakshadweep 1.01 2.10 N.A. N.A. 1.68 N.A. ψ 

Agatti Thermal-DG Lakshadweep 1.14 3.03 N.A. N.A. 2.70 N.A. ψ 

Kadmat Thermal-DG Lakshadweep 0.75 2.39 N.A. N.A. 1.65 N.A. ψ 

Kiltan Thermal-DG Lakshadweep 1.00 1.24 N.A. N.A. 1.10 N.A. ψ 

Chetlat Thermal-DG Lakshadweep 0.43 0.77 N.A. N.A. 0.69 N.A. ψ 

Bitra Thermal-DG Lakshadweep 0.10 0.17 N.A. N.A. 0.15 N.A. ψ 

Bangaram Thermal-DG Lakshadweep 0.14 0.26 N.A. N.A. 0.26 N.A. ψ 

Total (Lakshadeep, Union Territory) 28.57 32.14 11.16 24.12 592.00 245 

6 PUDUCHERRY POWER CORPORATION LTD. 

Karaikal CCGP Plant Thermal-G Puducherry 32.50 257.24 4851.52 189.00 257.24 5298.71 206 

7 TAMIL NADU ELECTRICITY BOARD 

Ennore Thermal-C T.N. 450 1754.63 62737.70 357.56 1438.79 45614.12 ψ 

Mettur Thermal-C T.N. 840 6147.19 117015.05 190.36 5040.69 159805.15 ψ 

Tuticorin Thermal-C T.N. 1050 7336.44 167126.61 227.80 6015.87 190721.00 ψ 

North Chennai Thermal-C T.N. 630 4242.64 91036.80 214.58 3478.97 110293.73 ψ 

Basin Bridge Thermal-N T.N. 120 61.01 14233.10 2332.95 50.03 1586.02 ψ 

Kovilkalappal Thermal-G T.N. 107.88 636.06 10642.00 167.31 521.57 16535.18 ψ 

Valuthur Thermal-G T.N. 95 574.99 11222.22 195.17 471.49 14947.57 ψ 

Kuttalam Thermal-G T.N. 101 63.51 8044.38 1266.55 52.08 1651.14 ψ 

Sub Total Thermal (TNEB) 20816.47 482057.88 231.58 17069.49 541153.91 ψ 

Pykara Hydro T.N. 69.95 159.11 674.40 42.39 130.47 4136.27 ψ 

Pykara Micro Hydro T.N. 2 9.87 56.10 56.82 8.10 256.69 ψ 

Moyar Hydro T.N. 36 179.51 469.44 26.15 147.20 4666.70 ψ 

Maravakandy Hydro T.N. 0.75 1.70 25.55 150.65 1.39 44.09 ψ 

Kundah I Hydro T.N. 60 346.03 638.00 18.44 283.75 8995.58 ψ 

Kundah II Hydro T.N. 175 902.02 1311.01 14.53 739.65 23449.22 ψ 

Kundah III Hydro T.N. 180 547.77 1226.33 22.39 449.17 14240.13 ψ 

Kundah IV Hydro T.N. 100 225.39 650.04 28.84 184.82 5859.29 ψ 

Kundah V Hydro T.N. 40 92.97 339.56 36.52 76.24 2416.92 ψ 


205


Parson Valley Hydro T.N. 30 53.03 1784.61 336.51 43.49 1378.67 ψ 

Mettur Dam Hydro T.N. 50 151.85 576.86 37.99 124.51 3947.43 ψ 

Mettur Tunnel Hydro T.N. 200 592.41 696.60 11.76 485.77 15400.48 ψ 

Barriage I Hydro T.N. 30 94.00 731.13 77.78 77.08 2443.56 ψ 

Barriage II Hydro T.N. 30 94.09 700.88 74.49 77.15 2445.93 ψ 

Barriage III Hydro T.N. 30 91.48 881.25 96.33 75.01 2378.10 ψ 

Barriage IV Hydro T.N. 30 72.83 1012.85 139.07 59.72 893.37 ψ 

Bavani Sagar RBC Hydro T.N. 8 36.64 658.41 179.68 30.05 952.61 ψ 

Lower Bhavani Sagar Hydro T.N. 8 46.25 306.40 66.24 37.93 1202.44 ψ 

Poonachi Micro Hydro T.N. 1 1.66 183.03 1102.59 1.36 43.15 ψ 

Sathanoor Hydro T.N. 7.50 5.15 653.27 1268.73 4.22 133.86 ψ 

Mukurthy Hydro T.N. 0.70 1.88 27.78 147.45 1.54 48.98 ψ 

Thirumurthy Dam Hydro T.N. 1.95 6.06 353.80 583.54 4.97 157.62 ψ 

Periyar Hydro T.N. 140 290.15 1855.80 63.96 237.92 7542.85 ψ 

Vaigai Hydro T.N. 6 26.69 144.75 54.24 21.88 693.72 ψ 

Suruliyar Hydro T.N. 35 121.16 712.62 58.81 99.35 3149.84 ψ 

Papanasam Hydro T.N. 28 136.41 663.82 48.66 111.86 3546.20 ψ 

Servalar Hydro T.N. 20 47.17 417.50 88.52 38.68 1226.15 ψ 

Sarkarpathy Hydro T.N. 30 153.40 152.32 9.93 125.79 3987.91 ψ 

Aliyar Hydro T.N. 60 183.20 372.48 20.33 150.22 4762.53 ψ 

Kadamparai Hydro T.N. 400 453.93 4339.54 95.60 372.22 11800.52 ψ 

Kadamparai Pump -402.92 N.A. N.A. N.A. N.A. N.A. 

Sholayar I Hydro T.N. 70 374.68 219.71 5.86 307.23 9740.25 ψ 

Sholayar II Hydro T.N. 25 63.91 125.90 19.70 52.40 1661.38 ψ 

Kodayar I Hydro T.N. 60 200.76 1262.10 62.87 164.62 5219.05 ψ 

Kodayar II Hydro T.N. 40 83.78 640.43 76.44 68.70 2178.04 ψ 

Lower Aliyar Hydro T.N. 2.50 10.77 258.94 240.49 8.83 279.90 ψ 

Pykara Ultimate Hydro T.N. 150 471.35 6892.44 146.23 386.50 12253.35 ψ 

Amaravathy Hydro T.N. 4 9.42 11.81 12.54 7.72 244.89 ψ 

Perunchani Hydro T.N. 1.30 1.15 127.86 1110.86 0.94 29.92 ψ 

Bhavani Kattalai(BKB) Hydro T.N. 30 90.95 4145.93 455.86 74.58 2364.30 ψ 

Sub Total Hydro (Tamil Nadu Electricity Board) 6027.66 36301.25 60.22 5273.03 166171.89 ψ 

Total (Tamil Nadu Electricity Board) 26844.13 518359.13 193.10 22342.52 707325.80 317 

(10/15) 

EASTERN REGION 

1 A.& N. ELECT. DEPTT. Thermal-DG A.& N. 20 194.40 18608.00 957.20 149.85 5007.00 334 

2 BIHAR STATE ELECTRICITY BOARD 

Barauni T P S Thermal-C Bihar 320 N.A. N.A. N.A. N.A. N.A. N.A. 

Muzaffarpur T P S Thermal-C Bihar 220 N.A. N.A. N.A. N.A. N.A. N.A. 

Total (Bihar State Electricity Board) N.A. N.A. N.A. N.A. N.A. N.A. 

3 BIHAR STATE HYDROELECTRIC POWER COR. 

Sone Westrn Link Canal H. E. 

Project, Dehri-On-Sone 

Hydro Bihar 6.60 16.50 440.28 267.00 16.12 322.43 ψ 

Sone Eastern Link Canal H.E. 

Project, Barun (Aurangabad) 

Hydro Bihar 3.30 8.57 235.86 276.00 8.26 165.18 ψ 

Eastern Gandak Canal H. E. 

PROJECT, Valmikinagar 

Hydro Bihar 15 20.67 786.76 381.00 19.80 396.10 ψ 

Kosi HE Stn. Katalya, Birpur 

(Supaul) 

Hydro Bihar 19.20 13.93 97.32 70.00 13.39 267.84 ψ 

Total (Bihar State Hydroelectric Power Corp.) 59.66 1560.22 261.50 57.58 1151.54 200 

206 

“A person without a sense of humor is like a wagon without springs-jolted by every pebble in the road.”


(11/15) 

4 JHARKHAND STATE ELECTRICITY BOARD 

Patratu T. P. S. Thermal-C Jharkhand 770 594.78 17249.00 N.A. N.A. N.A. ψ 

Sub Total Thermal (Jharkhand S. E. Board) 594.78 17249.00 N.A. N.A. N.A. ψ 

S. R. H. P. , Sikidiri Hydro Jharkhand 130 213.55 854.20 40.00 N.A. N.A. ψ 

Sub Total Hydro (Jharkhand S. E. Board) 213.55 854.20 40.00 N.A. N.A. ψ 

Total (Jharkhand S. E. Board) 808.33 18103.20 223.96 4246.40 131094.00 309 

5 ORISSA HYDRO POWER CORPORATION LTD. 

Hirakud Power System 

(HPS+Burla+Chiplima) 

Hydro Orissa 347.50 980.74 7458.83 76.00 955.78 6108.09 64 

Balimela H. E. Project Hydro Orissa 360 1831.90 4631.10 25.00 1800.16 9073.78 50 

Rengali H. E. Project Hydro Orissa 250 983.43 3474.15 35.00 955.94 3379.51 35 

Upper Kolab H. E. Project Hydro Orissa 320 1074.76 3058.90 28.00 1073.54 2351.41 22 

Upper Indravati H. E. Project Hydro Orissa 600 2979.44 12134.54 41.00 2948.40 17691.25 60 

MHEP(Joint) Hydro Orissa 114.75 434.43 N.A. N.A. 174.63 N.A. N.A. 

Total (Orissa Hydro Power Corpn. Limited) 7850.26 30757.52 39.18 7733.82 38604.04 50 

6 ORISSA POWER GENERATION CORPORATION LTD. 

Ib TPS, Banarpali Thermal-C Orissa 420 2734.30 29164.28 106.66 2734.30 44543.77 163 

7 SIKKIM, ENERGY & POWER DEPARTMENT 

L L H P (Lower Lagyap) Hydro Sikkim 12.00 31.17 178.6 57.30 N.A. N.A. ψ 

J P H Hydro Sikkim 2.10 0.00 31.68 N.A. N.A. N.A. ψ 

Rimbi - I Hydro Sikkim 0.60 0.00 19.15 N.A. N.A. N.A. ψ 

Rothak Hydro Sikkim 0.20 0.00 4.10 N.A. N.A. N.A. ψ 

Rongnichu -II Hydro Sikkim 2.50 0.00 29.12 N.A. N.A. N.A. ψ 

Chaten Hydro Sikkim 0.10 0.00 5.58 N.A. N.A. N.A. ψ 

Meyong Hydro Sikkim 4 5.10 32.81 64.33 N.A. N.A. ψ 

Rimbi - II Hydro Sikkim 1 0.00 10.26 N.A. N.A. N.A. ψ 

Upper Rongichu Hydro Sikkim 8 2.53 46.97 185.65 N.A. N.A. ψ 

Kalez Hydro Sikkim 2 0.00 37.80 N.A. N.A. N.A. ψ 

Lachung Hydro Sikkim 0.20 0.00 6.48 N.A. N.A. N.A. ψ 

Rabomchu Hydro Sikkim 3 7.24 N.A. 0.00 N.A. N.A. ψ 

Sub Total Hydro (Govt. of Sikkim, E. & P. Deptt.) 46.04 402.55 87.43 N.A. N.A. ψ 

D P H (Gangtok DG) Thermal-DG Sikkim 4 0.17 43.96 2585.88 N.A. N.A. ψ 

Sub Total Thermal (Govt. of Sikkim, E & P Dep.) 0.17 43.96 2585.88 N.A. N.A. ψ 

Total (Govt. of Sikkim, Energy & Power Deptt.) 46.21 446.51 96.63 32.05 770.54 240 

8 TENUGHAT VIDYUT NIGAM LIMITED 

Tenughat TPS Thermal-C Jharkhand 420 1794.78 43770.25 243.88 1599.81 30890.73 193 

9 WEST BENGAL- DURGAPUR PROJECTS LIMITED 

Durgapur Projects Power Stn. Thermal-C W.B. 701 1569.76 33724.22 215.00 1845.83 47322.84 256 

10 WEST BENGAL POWER DEVLOPMENT CORPORATION LTD. 

Kolaghat TPS (U 1-6) Thermal-C W.B. 1260 7107.53 115633.00 162.69 7107.53 120628.00 170 

Bakreswar TPS (U 1-3) Thermal-C W.B. 630 4570.40 77035.00 168.55 4570.40 75748.00 166 

Bandel TPS (U 1-5) Thermal-C W.B. 450 1966.98 37748.00 191.91 1966.98 36392.00 185 

Santaldih TPS (U 1-4) Thermal-C W.B. 480 1335.19 32470.00 243.19 1335.19 24361.00 182 

Total (W B P Dev. Corp. Ltd.) 14980.09 262886.00 175.49 14980.09 257129.00 172 

11 WEST BENGAL STATE ELECTRICITY DISCOM LTD. 

Jaldhaka H E P Hydro W.B. 35 115.07 861.84 74.90 N. A. N. A. ψ 

Ramam H E P Hydro W.B. 51 203.20 1685.81 82.96 N. A. N. A. ψ 


207


Teesta Canal Fallas Hydro W.B. 67.50 49.33 1963.37 398.00 N. A. N. A. ψ 

Purulia Pumped Storage Prjct. Hydro W.B. 900 387.91 28872.61 744.31 N. A. N. A. ψ 

Other Hydel Power Station Hydro W.B. 10.05 15.46 848.84 548.99 N. A. N. A. ψ 

Sub Total Hydro (W. B. S. E. D. C. LTD.) 770.97 34232.47 444.02 N. A. N. A. ψ 

Rudranagar Thermal-DG W.B. 0.50 0.73 83.07 1137.95 N. A. N. A. ψ 

Sub Total Thermal (W. B. S. E. D. C. LTD) 0.73 83.07 1137.95 N. A. N. A. ψ 

Total (W. B. S. E. D. C. LTD) 771.70 34315.54 444.67 15923.07 542643.00 341 

(12/15) 

NORTH EASTERN REGION 

1 ARUNACHAL PRADESH Hydro Ar..Pradesh 33.79 50673.04 619.40 122.00 N. A. N. A. N. A. 

2 ASSAM POWER GENERATION CORPORATION LTD. 

Namrup T.P.S Thermal-G Assam 134 504.85 10353.00 205.07 488.24 8616.13 176 

Lakuwa T.P.S Thermal-G Assam 120 484.09 11799.00 243.74 477.91 9100.59 190 

Sub Total Ther. Gas (Assam Power Gen. Corp. Ltd.) 988.94 22152.00 224.00 966.15 17716.72 183 

KLHEP(Assam Power Gen. 

Corp. Ltd.) 

Hydro Assam 100 509.20 5088.00 99.92 507.63 7048.61 139 

Total (Assam Power Gen. Corp. Ltd.) 1498.14 27240.00 181.83 1473.78 24765.33 168 

3 MEGHALAYA STATE ELECTRICITY BOARD 

MeSEB Hydel Power Station Hydro Meghalaya 185.20 663.06 6380.85 96.23 1058.10 31815.43 301 

4 MIZORAM POWER & ELECTRICITY DEPTT. 

Khawiva Hydro Mizoram 1.05 0.65 7.05 109.00 0.65 16.54 ψ 

Tuipui Hydro Mizoram 0.50 0.80 9.64 120.00 0.80 20.56 ψ 

Maicham-I Hydro Mizoram 2 4.91 13.15 27.00 4.91 125.72 ψ 

Teirei Hydro Mizoram 3 6.64 64.18 97.00 6.64 169.85 ψ 

Tuipanglui Hydro Mizoram 3 1.10 11.25 103.00 1.10 28.02 ψ 

Kautiabung Hydro Mizoram 3 1.84 25.22 137.00 1.84 47.06 ψ 

Sub Total Hydro (Mizoram Power & Elecy. Deptt.) 15.93 130.49 81.92 15.93 407.75 ψ 

Bairabi 

Thermal 

-HFO 

Mizoram 22.92 2.56 302.94 1182.00 2.56 65.63 ψ 

Lengpui Thermal -DG Mizoram 0.50 0.03 7.57 2375.00 0.03 0.82 ψ 

Sub Total Thermal (Mizoram Power & Elecy. Deptt.) 2.60 310.51 1196.57 2.60 66.45 ψ 

Total (Mizoram Power & Elecy. Deptt.) 18.52 441.00 238.08 18.52 474.20 234 

5 NAGALAND DEPTT. OF POWER 

D. G. Set Kma (As Standby) Thermal -DG Nagaland 0.70 0.73 43.22 592.00 0.73 19.71 ψ 

Sub Total Thermal (Nagaland Deptt. of Power) 0.73 43.22 592.00 0.73 19.71 ψ 

Likimro HEP Hydro Nagaland 24.00 96.44 2044.53 212.00 96.44 2603.88 ψ 

Dzuza MHP Hydro Nagaland 1.50 0.05 1.05 198.00 0.05 1.44 ψ 

Duilumroi -I Hydro Nagaland 0.54 0.23 4.80 211.00 0.23 6.15 ψ 

Duilumroi-II Hydro Nagaland 0.20 0.05 1.02 211.00 0.05 1.31 ψ 

Telangsao MHP Hydro Nagaland 0.60 0.25 5.42 215.00 0.20 5.44 ψ 

Sub Total Hydro (Nagaland Deptt. of Power) 97.02 2056.82 212.00 96.97 2618.22 ψ 

Total (Nagaland Deptt. of Power) 97.75 2100.04 214.84 97.70 2637.93 270 

6 TRIPURA STATE ELECTRICITY CORPORATION LTD. 

Rohit Gas Thermal Project Thermal -G Tripura 74 424.63 6896.55 162.41 418.26 7172.64 268 

Baramura Gas Thermal Project Thermal -G Tripura 21 159.23 2536.76 159.32 156.84 2689.61 268 

Sub Total Thermal (Tripura State Elecy. Corpn. Ltd.) 583.86 9433.31 161.57 575.10 9862.25 171 

Gumti Hydel Project Hydro Tripura 15 36.37 152.39 41.90 36.00 617.41 268 

Sub Total Hydro (Tripura State Elecy. Corpn. Ltd.) 36.37 152.39 41.90 36.00 617.41 268 

Total (Tripura State Electricity Corpn. Ltd.) 620.23 9585.70 154.55 611.10 10479.66 171 

PRIVATE 

208 

“Failing to plan is planning to fail.”


(13/15) 

1 CESC LTD., KOLKATA 

Budge Budge Thermal -C W.B. 500 4057.00 N.A. N.A. N.A. N.A. ψ 

Titagarh Thermal -C W.B. 240 1772.00 N.A. N.A. N.A. N.A. ψ 

Southern Thermal -C W.B. 135 1027.00 N.A. N.A. N.A. N.A. ψ 

New cossipore Thermal -C W.B. 100 452.00 N.A. N.A. N.A. N.A. ψ 

CESC LTD., KOLKATA 7308.00 N.A. N.A. N.A. 277500.00 386 

2 D L F POWER LIMITED 

Adamtilla Thermal -NG Assam 9 24.87 867.70 348.89 54.00 1099.59 204 

Banskandi Thermal -NG Assam 15.50 78.42 1786.44 227.82 93.00 2212.94 238 

Rajrappa Thermal -WR Jharkhand 11 35.49 1417.30 399.37 60.00 1822.27 304 

Gidi Thermal -WR Jharkhand 11 21.88 1479.24 676.10 60.00 1913.47 319 

Madhuband Thermal -WR Jharkhand 11 5.49 1726.43 3147.74 60.00 2186.60 364 

Total (D L F Power Limited.) 166.14 7277.11 438.02 326.99 9234.87 282 

3 ESSAR POWER LIMITED, HAZIRA 

Essar Power Limited, Hazira Thermal -G Gujarat 515 3514.90 52368.78 272.00 1927.70 53632.14 278 

4 ESSAR STEEL LIMITED, VIZAG 

Captive Power Plant Thermal -C A.P. 30 128.98 4921.31 382.00 5.81 217.75 375 

5 G M R ENERGY LIMITED 

G M R Energy Ltd. 

6 G M R Energy 

Vemagiri Power Generation 

Ltd. 

Thermal-N/ 

HSD 

7 G M R POWER CORPORATION PVT. LTD. 

Karnataka 239.42 512.761 48558.77 947.00 512.761 48558.47 947 

Thermal -G A.P. 388.50 274.55 17576.48 640.19 265.96 5366.56 202 

G M R Power Corporation Ltd Thermal -L Tamilnadu 200 1132.18 74259.42 655.90 1167.20 76556.37 656 

8 GOA ENERGY PRIVATE LIMITED 

Goa Energy Pvt Ltd(Videocon 

Co.) 

9 GOA SPONGE & POWER LIMITED 

Thermal -G Goa 30 58.5819 179.84 307.00 56.88 137.07 240 

Sarivordem, Division VII Thermal -C Goa 12 51382.00 1320.00 257.00 12734.00 296.00 233 

10 GUJARAT INDUSTRIES POWER COMPANY LTD. 

Power Plant (Station-I) Thermal -G Gujarat 145 1139.32 23782.14 209.00 1120.00 29782.49 266 

Power Plant(Station-II) Thermal -G Gujarat 160 1126.13 29883.91 265.00 1103.09 29664.30 269 

Surat Lignite Power 

Plant(SLPP) 

Thermal -LIG Gujarat 250 1878.54 27933.29 149.00 1666.33 34107.77 205 

Total (Thermal Gujarat Industries Power Company Ltd.) 4143.99 81599.34 196.91 3889.41 93554.56 241 

11 GUJ. PAGUTHAN ENERGY CORPORA. PVT. LTD. 

Paguthan CCPP Thermal -G+N Gujarat 654.73 4077.00 153901.00 377.44 4077.00 184981.00 454 

12 G V K INDUSTRIES LIMITED 

Jegurupadu CCPP Thermal -NG A.P. 216.82 1280.52 28767.69 225.00 1280.52 32049.53 250 


209


13 HINDALCO INDUSTRIES LIMITED 

Hirakud Power Thermal -C Orissa 367.50 1544.03 14156.5 91.69 33.27 514.78 155 

Renusagar Power Division 

(Captive Power Plant) 

Thermal -C U.P. 741.70 6343.50 88538.00 139.57 N. A. N. A. N. A. 

14 JAIPRAKASH POWER VENTURES LIMITED 

Vishnuprayag HEP Hydro Uttarakhand 400 1846.88 18899.31 102.00 1625.26 39107.74 241 

15 JAIPRAKASH HYDRO POWER LIMITED 

Baspa II HEP Hydro H.P. 300 1121.26 17029.00 152.00 1121.26 30763.00 274 

16 J S W ENERGY LTD. (JINDAL TH. POWER. CO. LTD.) 

JSWEL(Coal & Furnace Gas) Thermal -C Karnataka 260 2067.189 31215.82 151.00 2067.19 92508.33 448 

17 L V S POWER LIMITED 

L V S Power Limited Thermal -L A.P. 36.80 N.A. N.A. N.A. N.A. 2806.97 109 

18 MADURAI POWER COR. PVT LTD. (Balaji.) 

Madurai Power Corp. Pvt. Ltd. Thermal -L T.N. 106 523.84 38663.79 738.00 511.24 38663.79 756 

19 MALANA POWER COMPANY LTD. 

Malana H E P Hydro H. P. 86 273.83 46796.50 170.80 273.83 13221.17 483 

20 RATNAGIRI GAS AND POWER PRIVATE LTD. 

RGPPL, Anjanvel Thermal -G Maharashtra 1480 3665.00 N.A. N.A. 3665.00 107156.00 292 

21 RELIANCE INFRASTRUCTURE LTD. 

Dahanu TPS Thermal -C Maharashtra 500 4013.58 70060.75 175.00 4013.58 78564.00 196 

Rinfra-Goa Thermal -N Goa 48 326.83 27303.69 835.00 327.12 29795.42 911 

Rinfra-Samalkot Power Station 

Thermal 

-G+N 

A.P. 220 1137.05 23632.00 208.00 1137.05 30806.00 271 

Total (Reliance Infrastucture Limited) 5477.46 120996.44 220.90 5477.75 139165.42 254 

22 SAMALPATTI POWER COMPANY PVT. LTD. 

Samalpatti Power Co. Pvt. Ltd. Thermal -L T.N. 105.66 526.37 38169.63 725.14 516.93 38169.63 738 

23 TATA POWER COMPANY LIMITED 

Jojobera TPS, Jamshedpur Thermal -C Jharkhand 427.50 2910.00 26706.00 92.00 2910.00 61274.00 211 

Based Power Plant, Belgaum 

Thermal 

-LSFO 

Karnataka 81.30 234.00 18922.00 808.00 234.00 18922.00 808 

Sub Total Thermal(Tata Power Company Ltd.) 3144.00 45628.00 145.13 3144.00 80196.00 255 

Licensed Area Th+Hy Maharashtra 1777 11079.00 344784.00 311.20 11864.00 385422.00 325 

Total (Tata Power Co. Ltd.) 14223.00 390412.00 274.49 15008.00 465618.00 310 

24 TORRENT POWER LTD. 

Sabarmati Power House 

Thermal-C 

RFD/HSD 

400 3123.05 N.A. N.A. N.A. N.A. ψ 

CCPP-Vetwa Thermal -G Gujarat 100 537.49 N.A. N.A. N.A. N.A. ψ 

(14/15) 

Total (Torrent Power Ltd.) 3660.54 89193.27 243.66 4529.26 177690.62 392 

Note :- 

1. C : Coal; CA: Captive; DG: Diesel Generator; G: Gas; LIG: Lignite; MIC: Micro; N: Nathpa; N.A.: Not Available; NG: Natural Gas, WR: 

Washery Rejects, L: LSHS, ROR: Run of the River 

2. £ Damodar Valley Corporation have not furnished all particular for Gas Turbine Station 

3. ££ NTPC have not furnished net generation, total coct of generation & cost of generation, hence tariff for Sale of Power from NTPC stations is 

given. 

4. £££ Project wise break up of total energy sold, total revenue earned and rate of sale of power not given by the H P S E Board. 

210 



5. ££££ Project wise break up of total energy sold, total revenue earned and rate of sale of power not given by the P S E Board. 

(15/15) 

6. * Project wise break up of total energy sold, total revenue earned and rate of sale of power not given by the Uttar Pradesh R V U N Limited 

7. ** Project wise break up of total energy sold, total revenue earned and rate of sale of power not given by the Chhattisgarh S E Board 

8. *** Chhattisgarh S E Board not given all the particular for Mini Hydel Project 

9. **** Madhya Pradesh P G C L, Jabalpur not given all the particular for Madhikhera 

10. $ Project wise break up not given by the Andhra Pradesh Power Generation Corporation Ltd. 

11. $$ Project wise break up not given by the K S E Board 

12. $$$ Project wise break up not given by the Govt. of Sikkim 

13. $$$$ Project wise break up of total energy sold, total revenue earned and rate of sale of power not given by the W B S E D Company 

14. § Project wise break up not given by the Govt. of Arunachal Pradesh 

15. §§ Project wise break up not given by the C E S C Ltd., Kolkata 

16. §§§ Project wise break up of total energy sold, total revenue earned and rate of sale of power not given by the Hindalco Industries, Renusagar 

17 §§§§ Torrent Power Ltd. is an integrated utility. Rate of sale of power has the average tariff of power sold to retail consumers. 

2. Cost of Generation for Nuclear Power Corp. Ltd. is not available so tariff for sale of Power from various Atomic Power Stations of NPCIL is given. 

3. ** Project wise break up not given by the concerned authority. 

4. $ Installed Capacity not given by the concerned authority. 

5. $$ Satluj Jal Vidyut Nigam Ltd. Commercially operated during October,2003. 

6. $$$ Jai Prakash Hydro Power Ltd. Commissioned on 24/01/2003 

7. # Hirakud Power Ltd. , Unit-2 Commissioned in 2005-06 

8. ## Reliance Energy Ltd. Commissioned in 2002-03 

9. ### CESC Ltd. Kolkata (Mulajore) Shut down in 2003-04 

10. #### CESC Ltd. Kolkata not given the project wise Total Revenue Earned and Rate of Sale of Power 

11. *** Dhuvran(Gas), Gujarat State Electricity Corporation Ltd. Commissioned on 22nd, September, 2003. 

12. $$$$ Uttaranchal Jal Vidyut Nigam Limited not provided data for the year 2000-01 

13. Data of Bihae State Hydroelectric Corporation, taken for the period from 2000-01 to 2002-03 from B.S.E.B. 

14. ££ BBMB - Power generated by BBMB is transmitted to partner state constituents in agreed ratios in which they bear the expenditure of these 

generating stations. This power is then sold by the respective power Utilities/SEB’s to their consumers thereby 

15. £££ As per account which includes UI charges, Income tax reimbursement, arrears relating to earlier years etc. for the Neyveli Lignite 

Corporation Ltd. 

16. (*) There is no installed capacity for the Chakra station ( K P C L), since it is only a diversion scheme to divert water to the Linganamakki 

Reservoir. 

17. ((**)) Bhadra & BRBC Power House have the included installed capacity i.e. 39.20 MW in Karnataka Power Corporation Ltd. 

18. « Data of Anpara(Total Energy Sold, Total Revenue Earned & Rate of Sale of Power) written against Anpara A & Anpara B indicated by this 

symbol ( « ) for the year2000-2001 

19 «« Data of Obra (Total Energy Sold, Total Revenue Earned & Rate of Sale of Power) written against Obra A & Obra B indicated by this symbol ( 

« «) for the year2000-2001 

20 ««« Data of Harduaganj (Total Energy Sold, Total Revenue Earned & Rate of Sale of Power) written against Harduaganj B & Harduaganj C 

indicated by this symbol ( « « «) for the all years 

21. «««« Indira Sagar Project (Narmada Hydroelectric Dev. Coe.Ltd.), report received from 2003-2004 

22. § Station wise rate of sale of power not given therefore weighted average rate of sale of power taken for individual station Punjab State Electricity 

Board, Punjab. 

23. §§ Station wise rate of sale of power not given therefore weighted average rate of sale of power taken for individual station of CESC Ltd. 

Kolkata 

24. §§§ Station wise rate of sale of power not given therefore weighted average rate of sale of power taken for individual station of Himachal 

Pradesh State Electricity Board, 

25. @ Transmitted to REL Distribution division, Reliance Energy Limited, Santa Cruz-E, with additional purchase of energy from Tata Power Co. 

sold to consumers of Mumbai suburbs. 

2. § : NTPC have not furnished net generation, total cost of generation & cost of generation. 

3. ψ : Pooled rate of sale of power is given by the utility. 

4. £ : The energy generated by BBMB at its various project stations is transmitted to partner state constituents in the agreed ratio against which the 

expenditure is borne by them. 


211


Annexure-10A 

(Item 10.2) 

(1/4) 

All INDIA/SECTOR-WISE/ORGANISATION-WISE GENERATION TAR- 

GET/ACTUAL GENERATION FOR THE YEAR 2008-09 

THERMAL 


SECTOR/ORGANISATION PLF % TARGET (MU) ACTUAL (MU) 

N.T.P.C. 89.86 210300 206912.13 

NEYVELI CORP. 72.22 16282 15753.52 

D.V.C. 57.15 20757 15320.20 

N.E.E.P.C.O 2431 2434.11 

RGPPL 9600 5206.97 

VPGCL 11.62 578 224 

NSPCL 876 12.34 

TOTAL CENTRAL SECTOR 84.3 260824 245863.27 

STATE SECTOR 

HPGC 73.69 14776 13505.72 

IPGPCL 54.78 5778 5513.07 

J&KPDC 0 0.28 

PSEB 85.5 17951 18071.72 

RRVUNL 88.9 22675 21525.62 

UPRVUNL 61.6 23437 22352.7 

CSEB 85.79 12380 13191.69 

GMDCL 50.49 1314 1105.77 

GSECL 76.15 28467 27841.11 

GSEGL 1146 998.73 

MAHAGENCO 70.59 51195 46485.74 

MPPGCL 64.91 19681 16089.27 

APGENCO 87.67 29211 27134.78 

KPCL 70.84 14046 12158.1 

KSEB 234 653.81 

LAKSH 0 28.03 

PPCL 250 258.75 

TNEB 80.77 24832 23581.43 

A&N ADM 0 68.9 

BSEB 3.64 578 102.07 

DPL 50.61 3572 3078.16 

JSEB 13.77 1500 1013.14 

OPGC 86.78 3256 3192.82 

SIKKIM 0 0.13 

TVNL 60.52 1705 2226.48 

WBPDC 57.51 25145 18347.77 

APGPCL 47.42 1161 1242.08 

MIZORAM 0 5.49 



MPDC 0 0 

TRIPURA 474 608.18 

TOTAL STATE SECTOR 71.17 304764 280381.54 


PVT.UTILITY 

RIL 100.97 4200 4422.31 

CESC 87.07 7670 7894.5 

TATA PCL 87.61 10610 9841.66 

TOR. POW. (AECO) 98.73 3903 4006.83 

TOTAL PVT. SEC. UTILITY 91.0 26383 26165.3 

PVT.IPPs 

ABAN POWR 816 811.65 

BELLARY 20 126.08 

BSES(C) 300 843.99 

BSES(P) 881 986.88 

DLF ASSAM 0 92.03 

SECTOR/ORGANISATION PLF % TARGET (MU) ACTUAL (MU) 

DPSCLTD 0 142.88 

ESSAR 1900 1688.16 

GAUTAMI 468 23.6 

GIPCL 3271 2870.62 

GMR ENERG 200 769.44 

GTE CORP 4839 3969.16 

GVKP&IL 1387 1327.28 

JINDAL 1400 1251.17 

JPL 5840 6364.1 

KONA 382 0 

KONDAPALI 2121 2304.69 

LANCO 526 0 

LVS POWER 0 0 

MADURAI P 680 665.26 

PENNA 519 339.13 

PPNPGCL 2125 2152.39 

REL 341 320.76 

RPG 0 97.23 

SAMALPATI 680 680.28 

SPGL 1220 1412.67 

ST-CMSECP 1809 1792.06 

SUR.CH.PL 0 130.04 

TATA PCL (B) 100 439.61 

TATA PCL (J) 2375 2195.2 

TOR. POW. (SUGEN) 2535 76.78 

VASAVI 1260 1364.45 

VEMAGIRI 391 724.59 

TOTAL PVT. SEC. IPP 38386 35962.18 

(2/4) 


213


PVT. IPPS IMPORT 

GIPCL 313 1062.62 

ICCL 300 264.86 

NALCO 300 215.14 

TOTAL PVT. SEC. IMP. 913 1542.62 

TOTAL IPP & IMPORT 39299 37504.80 

TOTAL PVT. SECTOR 65682 63670.1 

NUCLEAR 

KAIGA 46.48 3964 2687.05 

KAKRAPARA 31.45 1013 1212.1 

M.A.P.P. 39.37 2026 1517.59 

N.A.P.S. 19.07 1013 734.91 

R.A.P.S. 34.78 3731 2254.6 

TARAPUR 51.45 7253 6309.64 

TOTAL NUCLEAR 40.77 19000 14715.89 

HYDRO 


BBMB 10083 11110.06 

DVC 325 431.84 

NEEPCO. 3287 2974.74 

NHDC 3767 2369.2 

NHPC 16200 16686.5 

SJVNL 6400 6611.5 

THDC 2850 3165.39 

TOTAL CENTRAL SECTOR 42912 43349.23 

STATE SECTOR 

HPGC 275 282.31 

HPSEB 1778 2023.61 

J&KPDC 2366 1611.81 

PSEB 4070 4227.43 

RRVUNL 1235 670.12 

UJVNL 4963 4576.13 

UPJVNL 1470 1099.31 

CSEB 354 294.16 

SECTOR/ORGANISATION TARGET (MU) ACTUAL (MU) 

GSECL 1114 547.83 

MAHAGENCO 4430 3991.4 

MPPGCL 2617 2456.82 

NVDA 18 0 

SSNNL 4730 2344.63 

APGENCO 8861 8158.78 

KSEB 7008 5841.78 

TNEB 4604 5376.53 

VVNL 11479 12911.58 

A&N ADM 7 9.77 

(3/4) 



BSHPC 71 49.46 

JSEB 151 237.71 

OHPC 6060 5662.35 

SIKKIM 50 47.85 

WBSEB 1302 943.72 

APGPCL 450 416.32 

ARUNACHAL 40 21.92 

MEGEB 568 555.37 

NAGALAND 100 71 

TRIPURA 50 50.35 

TOTAL STATE SECTOR 70221 64480.05 


PVT.UTILITY 

BHANDARDHARA 96 65.25 

BHIRA 950 211.95 

BHIRA PSS 0 355.63 

BHIVPURI 250 292.28 

GUNTUR 0 0.02 

KHOPOLI 250 277.01 

TAWA 40 0 

TOTAL PVT SEC. UTILITY 1586 1202.14 

PVT.IPPs 

BASPA 1213 1291.52 

CHAYADEVI 55 48.88 

HARANGI 24 14.09 

KUTHUNGAL 69 38.4 

MADHAVAMANTRI 22 22.07 

MALANA 350 351.46 

MANDAGERE 6 7.16 

MANJANADHA 10 0 

MANIYAR 33 25.20 

NARAYANPUR 40 39.68 

NERIA 24 20.43 

SHAHPUR 20 20.63 

SHIVPURA 90 83.43 

VISHNU PRAYAG 1775 2033.34 

TOTAL PVT SEC. IPPs 3731 3996.29 

TOTAL PVT. SECTOR 5317 5198.43 

(4/4) 


215


State 

Annexure-10B 

(Item 10.4) 

(1/6) 

SUMMARY OF STATE-WISE/REGION-WISE/SECTOR-WISE/PRIME 

MOVER-WISE INSTALLED CAPACITY FOR THE YEAR 2008-09 

INSTALLED CAPACITY (IN MW) OF POWER UTILITIES IN THE STATES/UTS LOCATED IN NORTHERN REGION 

INCLUDING ALLOCATED SHARES IN JOINT & CENTRAL SECTOR UTILITIES 

(As on 31.03.2009) 

Ownership 

Sector 

Modewise breakup 

Thermal 

Total 

Coal Gas Diesel 

Thermal Nuclear 

Hydro 

(Rene 

wable) 

RES ** 

( MNRE) 

Delhi State 320.00 600.40 0.00 920.40 0.00 0.00 0.00 920.40 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 1920.50 204.30 0.00 2124.80 47.08 585.06 0.00 2756.94 

Sub-Total 2240.50 804.70 0.00 3045.20 47.08 585.06 0.00 3677.34 

Haryana State 2142.50 0.00 3.92 2146.42 0.00 884.24 62.70 3093.36 

Private 0.00 0.00 0.00 0.00 0.00 0.00 6.00 6.00 

Central 375.57 532.04 0.00 907.61 76.16 447.16 0.00 1430.93 

Sub-Total 2518.07 532.04 3.92 3054.03 76.16 1331.40 68.70 4530.29 

Himachal 

Pradesh 

Jammu 

& 

Kashmir 

Grand 

Total 

State 0.00 0.00 0.13 0.13 0.00 393.60 185.115 578.85 

Private 0.00 0.00 0.00 0.00 0.00 386.00 0.00 386.00 

Central 95.41 60.89 0.00 156.30 14.08 761.24 0.00 931.62 

Sub-Total 95.41 60.89 0.13 156.43 14.08 1540.84 185.12 1896.47 

State 0.00 175.00 8.94 183.94 0.00 780.00 111.83 1075.77 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 198.59 127.09 0.00 325.68 68.00 689.50 0.00 1083.18 

Sub-Total 198.59 302.09 8.94 509.62 68.00 1469.50 111.83 2158.95 

Punjab State 2630.00 0.00 0.00 2630.00 0.00 2319.82 123.90 5073.72 

Private 0.00 0.00 0.00 0.00 0.00 0.00 37.57 37.57 

Central 546.21 259.72 0.00 805.93 151.04 711.75 0.00 1668.72 

Sub-Total 3176.21 259.72 0.00 3435.93 151.04 3031.57 161.47 6780.01 

Rajasthan State 2545.00 443.80 0.00 2988.80 0.00 987.84 30.25 4006.89 

Private 0.00 0.00 0.00 0.00 0.00 0.00 696.05 696.05 

Central 567.49 217.74 0.00 785.23 469.00 468.98 0.00 1723.21 

Sub-Total 3112.49 661.54 0.00 3774.03 469.00 1456.82 726.30 6426.15 

Uttar 

Pradesh 

State 4120.00 0.00 0.00 4120.00 0.00 527.40 25.10 4672.50 

Private 0.00 0.00 0.00 0.00 0.00 0.00 377.88 377.88 

Central 2373.31 541.16 0.00 2914.47 203.72 1078.09 0.00 4196.28 

Sub-Total 6493.31 541.16 0.00 7034.47 203.72 1605.49 402.98 9246.66 

Uttranchal State 0.00 0.00 0.00 0.00 0.00 1248.25 109.92 1358.17 

Private 0.00 0.00 0.00 0.00 0.00 400.00 0.05 400.05 

Central 232.80 68.25 0.00 301.05 16.28 307.48 0.00 624.81 

Sub-Total 232.80 68.25 0.00 301.05 16.28 1955.73 109.97 2383.03 

Chandigarh State 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 26.51 15.07 0.00 41.58 4.84 47.04 0.00 93.46 

Sub-Total 26.51 15.07 0.00 41.58 4.84 47.04 0.00 93.46 

Central - Unallocated 713.61 285.73 0.00 999.34 129.80 401.70 0.00 1530.84 

Total State 11757.50 1219.20 12.99 12989.69 0.00 7141.15 648.82 20779.66 

Northern Private 0.00 0.00 0.00 0.00 0.00 786.00 1117.55 1903.55 

Region Central 7050.00 2311.99 0.00 9361.99 1180.00 5498.00 0.00 16039.99 

Grand Total 18807.50 3531.19 12.99 22351.68 1180.00 13425.15 1766.37 38723.20 



INSTALLED CAPACITY (IN MW) OF POWER UTILITIES IN THE STATES/UTS LOCATED IN WESTERN REGION 


State 

Ownership 

Sector 

Thermal 



Total 

Thermal 

Nuclear 

Hydro 

(Rene 

wable) 

(2/6) 

(As on 31.03.2009) 

RES ** 

( MNRE) 

Grand 

Total 

Goa State 0.00 0.00 0.00 0.00 0.00 0.00 0.05 0.05 

Daman & 

Diu 

Private 0.00 48.00 0.00 48.00 0.00 0.00 30.00 78.00 

Central 279.18 0.00 0.00 279.18 0.00 0.00 0.00 279.18 

Sub-Total 279.18 48.00 0.00 327.18 0.00 0.00 30.05 357.23 

State 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 64.99 4.13 0.00 69.12 1.98 0.00 0.00 71.10 

Sub-Total 64.99 4.13 0.00 69.12 1.98 0.00 0.00 71.10 

Gujarat State * 4369.00 518.72 17.28 4905.00 0.00 772.00 24.30 5701.30 

Madhya 

Pradesh 

Private 640.00 1812.50 0.20 2452.70 0.00 0.00 1373.20 3825.90 

Central 1340.79 417.40 0.00 1758.19 825.00 0.00 0.00 2583.19 

Sub-Total 6349.79 2748.62 17.48 9115.89 825.00 772.00 1397.50 12110.39 

State 2807.50 0.00 0.00 2807.50 0.00 1703.67 71.76 4582.93 

Private 0.00 0.00 0.00 0.00 0.00 0.00 190.95 190.95 

Central 1473.60 252.91 0.00 1726.51 92.88 1520.00 0.00 3339.39 

Sub-Total 4281.10 252.91 0.00 4534.01 92.88 3223.67 262.71 8113.27 

Chhatisgarh State 1920.00 0.00 0.00 1920.00 0.00 120.00 18.05 2058.05 

Private 1000.00 0.00 0.00 1000.00 0.00 0.00 156.10 1156.10 

Central 392.90 0.00 0.00 392.90 0.00 0.00 0.00 392.90 

Sub-Total 3312.90 0.00 0.00 3312.90 0.00 120.00 174.15 3607.05 

Maharastra State 6546.00 912.00 0.00 7458.00 0.00 2888.83 216.71 10563.54 

Private 1900.00 180.00 0.00 2080.00 0.00 444.00 1942.50 4466.50 

Central 1916.00 2617.28 0.00 4533.28 852.06 0.00 0.00 5385.34 

Sub-Total 10362.00 3709.28 0.00 14071.28 852.06 3332.83 2159.21 20415.38 

Dadra & State 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Nagar Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Haveli Central 52.19 26.61 0.00 78.80 1.98 0.00 0.00 80.78 

Sub-Total 52.19 26.61 0.00 78.80 1.98 0.00 0.00 80.78 


Total State 15642.50 1430.72 17.28 17090.50 0.00 5484.50 330.87 22905.87 

Western Private 3540.00 2040.50 0.20 5580.70 0.00 444.00 3692.75 9717.45 


Grand Total 25652.50 6983.22 17.48 32653.20 1840.00 7448.50 4023.62 45965.32 


217


INSTALLED CAPACITY (IN MW) OF POWER UTILITIES IN THE STATES/UTS LOCATED IN SOUTHERN REGION 


State 

Ownership 

Sector 


Thermal 


Total 

Thermal Nuclear 

Hydro 

(Rene 

wable) 

(3/6) 

(As on 31.03.2009) 

Grand Total 

RES ** 

( MNRE) 

Andhra State 3342.50 0.00 0.00 3342.50 0.00 3572.93 182.432 7097.86 

Pradesh Private 0.00 1603.40 36.80 1640.20 0.00 0.00 486.225 2126.43 

Central 2377.38 0.00 0.00 2377.38 37.41 0.00 0.00 2414.79 

Sub-Total 5719.88 1603.40 36.80 7360.08 37.41 3572.93 668.66 11639.08 

Karnataka State 1970.00 0.00 127.92 2097.92 0.00 3518.20 452.4 6068.52 

Private 260.00 220.00 106.50 586.50 0.00 0.00 1428.14 2014.64 

Central 1072.67 0.00 0.00 1072.67 190.90 0.00 0.00 1263.57 

Sub-Total 3302.67 220.00 234.42 3757.09 190.90 3518.20 1880.54 9346.73 

Kerala State 0.00 0.00 234.60 234.60 0.00 1769.10 119.02 2122.72 

Private 0.00 174.00 21.84 195.84 0.00 0.00 0.02 195.86 

Central 765.38 350.00 0.00 1115.38 80.09 0.00 0.00 1195.47 

Sub-Total 765.38 524.00 256.44 1545.82 80.09 1769.10 119.04 3514.05 

Tamil State 2970.00 523.20 0.00 3493.20 0.00 2093.95 110.55 5697.70 

Nadu Private 250.00 503.10 411.66 1164.76 0.00 0.00 4269.093 5433.85 

Central 2299.81 0.00 0.00 2299.81 657.39 0.00 0.00 2957.20 

Sub-Total 5519.81 1026.30 411.66 6957.77 657.39 2093.95 4379.64 14088.75 

NLC State 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 100.17 0.00 0.00 100.17 0.00 0.00 0.00 100.17 

Sub-Total 100.17 0.00 0.00 100.17 0.00 0.00 0.00 100.17 

Pondicherry State 0.00 32.50 0.00 32.50 0.00 0.00 0.00 32.50 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.02 

Central 207.01 0.00 0.00 207.01 17.09 0.00 0.00 224.10 

Sub-Total 207.01 32.50 0.00 239.51 17.09 0.00 0.02 256.62 


Total State 8282.50 555.70 362.52 9200.72 0.00 10954.18 864.40 21019.30 

Southern Private 510.00 2500.50 576.80 3587.30 0.00 0.00 6183.50 9770.80 


Grand 

Total 16682.50 3406.20 939.32 21028.02 1100.00 10954.18 7047.90 40130.10 



INSTALLED CAPACITY (IN MW) OF POWER UTILITIES IN THE STATES/UTS LOCATED IN EASTERN REGION 


State 

Ownership 

Sector 

Thermal 



Total 

Thermal 

Nuclear 

Hydro 

(Renewable) 

(4/6) 

(As on 31.03.2009) 

Grand Total 

RES ** 

( MNRE ) 

Bihar State 540.00 0.00 0.00 540.00 0.00 0.00 50.40 590.40 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 1306.59 0.00 0.00 1306.59 0.00 73.00 0.00 1379.59 

Sub-Total 1846.59 0.00 0.00 1846.59 0.00 73.00 50.40 1969.99 

Jharkhand State 1260.00 0.00 0.00 1260.00 0.00 130.00 4.05 1394.05 

West 

Bengal 

Private 360.00 0.00 0.00 360.00 0.00 0.00 0.00 360.00 

Central 352.52 0.00 0.00 352.52 0.00 46.00 0.00 398.52 

Sub-Total 1972.52 0.00 0.00 1972.52 0.00 176.00 4.05 2152.57 

State 4575.00 100.00 12.06 4687.06 0.00 1022.00 99.50 5808.56 

Private 1081.38 0.00 0.14 1081.52 0.00 0.00 0.05 1081.57 

Central 701.56 0.00 0.00 701.56 0.00 140.00 0.00 841.56 

Sub-Total 6357.94 100.00 12.20 6470.14 0.00 1162.00 99.55 7731.69 

DVC State 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 3100.00 90.00 0.00 3190.00 0.00 196.00 0.00 3386.00 

Sub-Total 3100.00 90.00 0.00 3190.00 0.00 196.00 0.00 3386.00 

Orissa State 420.00 0.00 0.00 420.00 0.00 2067.93 32.30 2520.23 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 1445.23 0.00 0.00 1445.23 0.00 107.00 0.00 1552.23 

Sub-Total 1865.23 0.00 0.00 1865.23 0.00 2174.93 32.30 4072.46 

Sikkim State 0.00 0.00 5.00 5.00 0.00 0.00 41.11 46.11 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 71.98 0.00 0.00 71.98 0.00 75.00 0.00 146.98 

Sub-Total 71.98 0.00 5.00 76.98 0.00 75.00 41.11 193.09 

Central - Unallocated 1232.12 0.00 0.00 1232.12 0.00 77.00 0.00 

Total State 6795.00 100.00 17.06 6912.06 0.00 3219.93 227.36 10359.35 

Eastern Private 1441.38 0.00 0.14 1441.52 0.00 0.00 0.05 1441.57 


Grand Total 16446.38 190.00 17.20 16653.58 0.00 3933.93 227.41 20814.92 


219


INSTALLED CAPACITY (IN MW) OF POWER UTILITIES IN THE STATES/UTS LOCATED IN NORTH-EASTERN 

REGION INCLUDING ALLOCATED SHARES IN JOINT & CENTRAL SECTOR UTILITIES 

State 

Ownership 

Sector 


(5/6) 

(As on 31.03.2009) 

Grand Total 

Thermal 

Total 

Hydro RES ** 

Coal Gas Diesel Thermal Nuclear (Renewable) ( MNRE ) 

Assam State 60.00 239.00 20.69 319.69 0.00 100.00 27.11 446.80 

Private 0.00 24.50 0.00 24.50 0.00 0.00 0.00 24.50 

Central 0.00 178.00 0.00 178.00 0.00 331.00 0.00 509.00 

Sub-Total 60.00 441.50 20.69 522.19 0.00 431.00 27.11 980.30 

Arunachal State 0.00 0.00 15.88 15.88 0.00 0.00 45.24 61.12 

Pradesh Private 0.00 0.00 0.00 0.00 0.00 0.00 0.02 0.02 

Central 0.00 21.00 0.00 21.00 0.00 98.00 0.00 119.00 

Sub-Total 0.00 21.00 15.88 36.88 0.00 98.00 45.26 180.14 

Meghalaya State 0.00 0.00 2.05 2.05 0.00 156.00 31.03 189.08 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 0.00 26.00 0.00 26.00 0.00 73.00 0.00 99.00 

Sub-Total 0.00 26.00 2.05 28.05 0.00 229.00 31.03 288.08 

Tripura State 0.00 127.50 4.85 132.35 0.00 0.00 16.01 148.36 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 0.00 33.00 0.00 33.00 0.00 62.00 0.00 95.00 

Sub-Total 0.00 160.50 4.85 165.35 0.00 62.00 16.01 243.36 

Manipur State 0.00 0.00 45.41 45.41 0.00 0.00 5.45 50.86 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 0.00 26.00 0.00 26.00 0.00 81.00 0.00 107.00 

Sub-Total 0.00 26.00 45.41 71.41 0.00 81.00 5.45 157.86 

Nagaland State 0.00 0.00 2.00 2.00 0.00 0.00 28.67 30.67 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 0.00 19.00 0.00 19.00 0.00 53.00 0.00 72.00 

Sub-Total 0.00 19.00 2.00 21.00 0.00 53.00 28.67 102.67 

Mizoram State 0.00 0.00 51.86 51.86 0.00 0.00 17.47 69.33 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Central 0.00 16.00 0.00 16.00 0.00 34.00 0.00 50.00 

Sub-Total 0.00 16.00 51.86 67.86 0.00 34.00 17.47 119.33 


Total State 60.00 366.50 142.74 569.24 0.00 256.00 170.98 996.22 

North- 

Eastern Private 0.00 24.50 0.00 24.50 0.00 0.00 0.02 24.52 


Grand Total 60.00 766.00 142.74 968.74 0.00 1116.00 171.00 2255.74 



INSTALLED CAPACITY (IN MW) OF POWER UTILITIES IN THE ISLANDS 

(As on 31.03.2009) 

State 

Ownership 


Grand Total 

Sector 

Thermal 

Total 

Hydro RES ** 

Coal Gas Diesel Thermal Nuclear (Renewable) ( MNRE ) 

Andaman & State 0.00 0.00 40.05 40.05 0.00 0.00 5.25 45.30 

Nicobar Private 0.00 0.00 20.00 20.00 0.00 0.00 0.10 20.10 

Central 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Sub-Total 0.00 0.00 60.05 60.05 0.00 0.00 5.35 65.40 

Lakshadweep State 0.00 0.00 9.97 9.97 0.00 0.00 0.00 9.97 

Private 0.00 0.00 0.00 0.00 0.00 0.00 0.76 0.76 

Central 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Sub-Total 0.00 0.00 9.97 9.97 0.00 0.00 0.76 10.73 

Total 

State 0.00 0.00 50.02 50.02 0.00 0.00 5.25 55.27 

Islands Private 0.00 0.00 20.00 20.00 0.00 0.00 0.86 20.86 

Central 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 

Grand Total 0.00 0.00 70.02 70.02 0.00 0.00 6.11 76.13 

(6/6) 


221


Annexure-11A 

(Item 11.3) 

50000 MW H.E. INITIATIVE 

LOW TARIFF HE SCHEMES UNDER SURVEY & INVESTIGATION / 

PREPARATION OF DPR IN NORTH-EASTERN REGION 

(1/3) 

As on 31.03.2009 

Sl. 

No. 

Name Of 

Scheme 

State River Type Basin Agency Installed 

Capacity 

(MW) 

Original 

Schedule 

for DPR 

Revised 

Schedule 

for DPR 

Status / Remarks 

A. Schemes for which DPRs have been prepared 

1 Talong Ar.P Kameng STO Kameng GMR Ltd. 300 - - DPR prepared in 

March’06 for 160 MW. 

2 Badao Ar.P Kameng ROR Kameng NEEPCO 120 - - Consent to NEEPCO 

for Preparation of DPR 

only. DPR prepared in 

April’06 for 60 MW 

3 Dibbin Ar.P Bichom ROR Kameng KSK 

Electricity 

Financing 

India Ltd. 

4 Demwe Ar.P Lohit STO Lohit Athena Energy 

Ventures Pvt. 

Ltd. 

100 - - DPR prepared in 

Sep.’07 for 125 MW. 

3000 - - DPR of this scheme by 

name Demwe Lower 

(1630 MW) has been 

submitted in Sep’08. 

5 Mawhu Meghalaya Umiew ROR Barak NEEPCO 120 - - DPR prepared in 

April’07 for 90 MW. 

B. Schemes under Survey & Investigation 


NIL 

STATE SECTOR 

IPP 

TOTAL 3640 

6 Nongkolait Meghalaya Umangi ROR Barak MeSEB 120 6/07 3/11 Survey & Investigation 

in progress 

7 Selim Meghalaya Barak STO Barak MeSEB 170 3/09 3/11 S&I in Progress 

TOTAL STATE SECTOR 290 

8 Umduna Meghalaya Barak ROR Barak Eta Star 

Infrastructure 

Ltd 

9 Tato-II Ar.P Siyom ROR Siang Reliance 

Energy Ltd. 

10 Hirong Ar.P Siyom ROR Siang Jai Prakash 

Associates Ltd. 

57 3/09 3/10 MOA signed in 

Dec’07. S&I in 

progress 

700 3/08 5/09 S&I in progress. 

500 3/08 9/09 S&I in progress. 



(2/3) 

11 Hutong Ar.P Lohit STO Lohit Mountain Falls 

Ltd. 

12 Kalai Ar.P Lohit STO Lohit Mountain Falls 

Ltd. 

13 Naying Ar.P Siyom ROR Siang D.S. 

Constructions 

Ltd. 

3000 3/09 12/09 State Govt. wants ROR 

instead of Storage 

scheme. Scheme split 

in two projects viz. 

Hutong-I (588 MW) & 

Hutong-II (1250 MW). 

Hutong-II (1250 MW) 

allotted to Mountain 

Falls Ltd. in Nov.’06 / 

S&I in progress. 

2600 3/09 2/10 State Govt. wants ROR 

instead of Storage 

scheme. Scheme split 

in two projects viz. 

Kalai-I (1450 MW) & 

Kalai-II (1200MW). 

Kalai-I (1450 MW) 

allotted to Mountain 

Falls Ltd. in Nov.’06 / 

S&I in progress. 

1000 3/08 7/09 S&I in progress. 

TOTAL IPP 7857 

Total I.C. (MW) 8147 

C. Low Tariff HE Schems Work held up (NER) 

14 Naba Ar.P Subansiri ROR Subansiri - 1000 - - MOEF Problem due 

to stay by Hon’ble 

Supreme Court for 

projects upstream of 

Lower Subansiri. 

15 Niare Ar.P Subansiri ROR Subansiri - 800 - - MOEF Problem due 





16 Oju-II Ar.P Subansiri ROR Subansiri - 1000 - - MOEF Problem due 





17 Oju-I Ar.P Subansiri ROR Subansiri - 700 - - MOEF Problem due 





18 Kameng-II 

(Bhareli-II) 

Ar.P Kameng ROR Kameng Mountain Falls 

( India) Ltd. 

600 - - Consent for 

Implementation. 

MOEF site clearance 

awaited. ( Pakhe wild 

life sanctuary) 


223


(3/3) 

19 Kameng-I 

(Bhareli-I) 

Ar.P Kameng ROR Kameng NEEPCO 1120 - - Stage-I estimates 

cleared in March’05. 

Consent for 

implementation. 

MOEF site clearance 

awaited. (Pakhe wild 

life sanctuary) 

20 Kameng 

Dam 

Ar.P Kameng - Kameng KSK 

Electricity 

India Ltd. 

600 - - MOEF issues 

involved. Review of 

submergence issues of 

Seppa town. 

21 Kapaklayak Ar.P Kameng ROR Kameng Yet to be 

decided 

22 Etalin Ar.P Dibang ROR Dibang Yet to be 

decided 

23 Attunli Ar. P Dibang ROR Dibang Yet to be 

decided 

160 - - DPR to be prepared 

by NEEPCO, Difficult 

access. 

4000 - - NTPC expressed its 

inability to pay upfront 

money. The project 

stands withdrawn by 

Govt. of Arunachal 

Pradesh vide letter da. 

6.11.07 

500 - - NTPC expressed its 

inability to pay upfront 

money. The project 

stands withdrawn by 

Govt. of Arunachal 

Pradesh vide letter da. 

6.11.07 

24 Nongnaw Meghalaya Umangi ROR Barak MeSEB 50 - - EOI invited for 

allotment to IPP 

25 Rangmaw Meghalaya Umangi ROR Barak MeSEB 65 - - EOI invited for 

allotment to IPP 

TOTAL 10595 

GRAND TOTAL 22382 



Sl. 

No 

Details of New Thermal Power Projects in 

North Eastern States 


1. ASSAM 

Margherita TPP by M/s 

NEEPCO under JV with 

APGCL 

2. MEGHALAYA 

a. West Khasi Hill TPP by M/s 

NEEPCO 

b. Garo Hills TPP by M/s 

NEEPCO 

3. TRIPURA 

Monarchak CCGT by M/s 

NEEPCO 

Capacity 

(MW) 

Total 1094 

Brief status 

250 Empanelment of consultants for 

preparation of FR/DPR has been made 

earlier by NEEPCO. 


preparation of FR/DPR has been made. 

Detailed tender shall be invited on receipt 

of State Govt. clearance. 


preparation of FR/DPR has been made. 

Detailed tender for preparation of FR/ 

DPR from the empanelled consultants 

will be invited. 

104 Project was recommended in PIB 

meeting held on 20.01.09 and being 

posed for CCEA approval 

Annexure-11B 

(Item-11.8) 

Problems/Bottlenecks 

(1/1) 

- Subject to availability of coal from 

the Makum coalfield from ECL 

-Joint Venture Company (JVC) 

agreement to be signed between 

NEEPCO & APGCL. All activities 

to be initiated by Joint Venture 

Company. 


the Langrin coalfield from ECL 

- Proposal for implementation of the 

project in Joint Venture mode with 

the State Govt. was submitted on 

28.8.08. Decision of the State Govt. 

is awaited. 


the Simsang coalfield from ECL 

- Availability of final decision from 

State Govt. regarding development of 

project 

- 


225


Tours/Training Abroad of CEA Officers during 

the year 2008-09 

Annexure- 12A 

(Item No.12.2) 

(1/3) 

S. 

No. 

Name 

S/Shri 

Designation Name of the programme Venue Duration 

1. Rakesh Nath Chairperson Review the progress of the projects under 

implementation and Plan for new initiative under the 

programme 

2. V.S. Verma Member (Plg.) Review the progress of the projects under 

implementation and Plan for new initiative under the 

programme 

3. Gurdial Singh Member (Hydro) 3 rd Meeting of Punatsangchhu Hydroelectric Project 

Authority (PHPA) as permanent invitee & 26 th Meeting 

of Tala Hydroelectric Project Authority THPA as special 

invitee. 

4. Gurdial Singh Member (Hydro) 3 rd Meeting of India-Nepal Joint Committee on Water 

Resources as Indian delegate 

Germany 

Germany 

Bhutan 

Kathmandu, 

Nepal 

14.7.2008 to 

19.7.2008 

14.7.2008 to 

19.7.2008 

7.8.2008 to 

11.8.2008 

28.9.2008 to 

1.10.2008 

5. A.K. Gupta Chief Engr. 

(TRM) 

Joint meeting among DVC, REL & M/s SEC at 

Shanghai regarding Raghunathpur TPP, DVC 

China 

26.4.2008 to 

2.5.2008 

6. U.S. Sharma Chief Engr. 

(Legal) 

Asia Pacific Partnership- US peer Review of coal fired 

under the power generation & transmission task force 

USA 

28.4.2008 to 

2.5.2008 

7. M.S. Puri Chief Engr. 

(Coord.) 

Power Engg. & Management under SAARC at Seoul South Korea 15.5.2008 to 

30.5.2008 

8. Y.P. Taneja C.E. (HE&TD) 3 rd Meeting of PHPA for Punatsangchhu-I HEP (6x200 

MW) and 26 th meeting of the THPA for Tala HEP at 

Thimpu, Bhutan 

Bhutan 

7.8.2008 to 

11.8.2008 

9. Suresh Chander Chief Engr. 

(TE&TD) 

Visit to Manufacturing works of super critical units Japan 29.9.2008 to 

1.10.2008 


(TRM) 

Part of delegation from NTPC reg. exploring the 

possibility of acquisition of stake in coal block in 

Indonesia 

Indonesia 

17.10.2008 to 

20.10.2008 


(TRM) 

Meeting with Ministers and Senior Officials, Govt. of 

Mozambique as a part of NTPC delegation reg.coal 

mines & setting up of power plant 

Mozambique 

16.2.2009 to 

19.2.2009 

12. S.Seshadri Chief Engr. (TPI) Visit to the works of M/s Shanghai Electric Corpn. Ltd., 

China & Thermal Power Stations in China 

China 

3.3.2009 to 

6.3.2009 

13. L.D. Papney Director 

(TE&TD) 

Inspection of BTG equipment at Subvendor Working 

M/s Shanghai Electric Corporation, China for 

HPGCLL’s 2x600 MW, Hissar TPP 

China 

2.4.2008 to 

13.4.2008 



(2/3) 

14. D.K. Gilhotra Director 

(TE&TD) 

Participation in the joint meeting among DVC,REL and 

M/s SEC, Shanghai, reg. Raghunathpur TPP, DVC 

China 

25.4.2008 to 

2.5.2008 

15. P.C. Kureel Director 

(HE&TD) 

Member of the multi-disciplinary team of experts from 

CEA, CWC & WAPCOS for finalizing & optimizing of 

the project components for Punatsangchhu HEP Stage-I 

(6x200MW) 

Bhutan 

30.4.2008 to 

5.5.2008 

16. K.N. Garg Director (HP&I) Member of the multi-disciplinary team of experts from 

CEA, CWC & WAPCOS for finalizing & optimizing of 

the project components for Punatsangchhu HEP Stage-I 

(6x200MW) 

Bhutan 

30.4.2008 to 

5.5.2008 

17. C.S. Kasana Director 

(HE&RM) 

Inspection of Turbine Runner of Myntdu (Leshka) H.E. 

Project (2x42 MW), Meghalaya (MeSEB) at the works 

of M/s V A Tech, Algete, Madrid, Spain 

Spain 

12.5.2008 to 

15.5.2008 

18. Gautam Ray Director 

(SP&PA) 

To attend Cigre Session 2008 Paris 24.8.2008 to 

29.8.2008 

19. A.K. Aggarwal Director (HRD) To attend Cigre Session 2008 Paris 24.8.2008 to 

29.8.2008 

20. Sanjay Sharma Director 

(TE&TD) 

Inspection of equipments for Hissar TPS at Shanghai 

Electric Works 

China 

16.9.2008 to 

21.9.2008 

21. Moti Lal Director 

(HE&TD) 

Presentation on works progressed so far in respect 

to DPR preparation of Punatsangchhu HEP Stage-II 

(6x165 MW) at Thimpu and held discussions with Royal 

Govt. of Bhutan on the matter and subsequently visit to 

the project site. 

Bhutan 

17.11.2008 to 

22.11.2008 

22. Dr.(Ms.) Srabani 

Guha 

Director 

(Economic Cell) 

“Financial Market and New Financial Instruments” 

jointly organized by IMF and Govt. of Singapore 

Singapore 

8.12.2008 to 

19.12.2008 

23. A.K. Mishra Director(OM) Study tour on O&M under Indo-German Cooperation 

Programme (IGEN) 

Germany 

1.3.2009 to 

14.3.2009 

24. Sanjay Sharma Director 

(TE&TD) 

Study tour on O&M under Indo-German Cooperation 


Germany 

1.3.2009 to 

14.3.2009 

25 B.K.Sharma Director(C&E) Study- cum Familiarization Tour under IGEN Germany 1.3.2009 to 

14.3.2009 

26 Alok Saxena Director (OM) Study tour on O&M under Indo-German Cooperation 


Germany 

22.3.2009 to 

4.4.2009 

27 L.D.Papney Director 

(TE&TD) 

To visit manufacturing works of M/s Shanghai Electric 

Corporation Ltd. and Thermal Power Stations in China 

China 

3.3.2009 to 

6.3.2009 

28. Bhai Lal Director (TRM) Study cum familiarization & interchange best practices 

of power plant 

Germany 

22.3.2009 to 

4.4.2009 

29. Sharad K 

Varshmey 

Dy.Director 

(TPI) 

“Coal Fired Power Generation Course” by NEDO’s 

Clean Coal Technology Training Programme 

Japan 

8.11.2008 to 

29.11.2008 


227


(3/3) 

30. Smt. Ammi Topo Dy. Director 

(IRP) 



Japan 

8.11.2008 to 

29.11.2008 

31. V.K. Singh Dy.Director 

(IRP) 



Japan 

8.11.2008 to 

29.11.2008 

32. Irfan Ahmed Dy. Director 

(OM) 



Japan 

8.11.2008 to 

29.11.2008 

33. Venkateswarlu T. Dy.Director 

(TPM) 



Japan 

8.11.2008 to 

29.11.2008 

34. Pradeep Kumar Dy.Director 

(HP&I) 

Presentation on works progressed so far in respect 

to DPR preparation of Punatsangchhu HEP Stage-II 

(6x165 MW) at Thimpu and held discussions with Royal 

Govt. of Bhutan on the matter and subsequently visit to 

the project site. 

Bhutan 

17.11.2008 to 

22.11.2008 

35. Balbir Singh Dy.Director 

(TPM) 

Study cum Familiarization & Interchange Best Practices 

of Power Plant 

Germany 

22.3.2009 to 

4.4.2009 

36 Smt. Rehana 

Sayeed 

Assistant 

Director 

Study- cum Familiarization Tour under IGEN Germany 22.3.2009 to 

4.4.2009

ANNUAL REPORT - Infraline

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