CONCEPT PAPER
ON
ACCELERATION OF ENERGY EFFICIENT RENOVATION AND MODERNIZATION AND
LIFE EXTENSION (R&M & LE) OF OLDER COAL BASED THERMAL POWER UNITS, INTRODUCTION
OF CONCURRENT ENERGY EFFICIENT R&M AND LE (CEE R&M AND LE) OF COAL BASED
THERMAL POWER UNITS IN OPERATION, UNDER CONSTRUCTION AND NEW UNITS OF STATE POWER
UTILITIES AND THEIR FUNDING.
DECEMBER, 2013
PART-2
BY
Prahalad Rao, Consultant
(MOB:9212151469)
1.0
INTRODUCTION OF CONCURRENT ENERGY EFFICIENT RENOVATION AND MODERNIZATION AND LE (CEE R&M AND LE) PROGRAM AND PROVISIONING FUNDS FOR COAL BASED THERMAL POWER UNITS IN OPERATION, UNDER CONSTRUCTION AND NEW UNITS.
1.1 CONCURRENT ENERGY EFFICIENT R&M AND LE (CEE – R&M AND LE) - THE LOGIC AND THE NEED
1.1.1 The concept of R&M and LE is presently
confined to only older coal based thermal power units in the country. This suggests
that coal based thermal power units in operation are to be taken up for EE R&M
and LE on completion of their life cycle. Till then the utilities will be undertaking
only routine operation and maintenance works to the extent allocation of funds are
available to them as revenue expenditure to keep the plant running. Experience has
shown that routine O&M fails to focus on major deficiencies started developing
in the unit. These become noticeable only through Energy Audit and Condition Assessment
studies of the unit Such studies are able to identify as precisely as possible unseen
major technical and operational defects affecting the operational efficiency resulting
in sub optimum utilization of the unit capacity.
1.1.2 EE R&M and LE studies and implementation
of measures recommended therein is considered normally not feasible during the operation
life time of the unit since it involves sizeable capital expenditure compared to
revenue expenditure for routine O&M. Therefore, the utilities have been shying
away from initiating action for such studies during operational life of the unit.
Longer shut down period normally needed for EE R&M and LE when the State is
undergoing shortage of power and lack of adequate financial resources to capital
expenditure are the factors that stop the utilities from moving towards that end.
1.1.3 The need for taking up CEE R&M and
LE of units in operation is suggested for following reasons::
(a) CEE R&M and LE can be carried out within
25%-30% of EPC cost of a new generating unit of indigenous origin if undertaken
during operational life time of the plant compared to 40%-50% or more of the above
cost when undertaken on completion of life cycle of the unit if the unit continues
to be in operational condition.
(b) This is so because periodical CEE R&M
enables early detection of defects impacting operational efficiency of the unit
due to technical and operational deficiencies and correction of defects by up-gradation
through available technology.
(c) CEE R&M prevents growth and occurrence
of defects that would have developed otherwise in the unit and enhances its operational
efficiency on a continual and assured basis with increasing energy generation and
revenue earning capacity as well as automatically lengthens life of the unit beyond
its life cycle as a result of its periodical attention and up-gradation compared
to EE R&M and LE on completion of its life cycle involving higher capital cost
with no certainty and assurance of the anticipated improvements and efficiency due
to surprises and uncertainty of adaptability and integration of the available technology
at that time with older technology of the unit.
(d) CEE R&M and LE will eliminate EE R&M
and LE of the unit on completion of its life cycle since the unit continues to maintain
sound technical health even at the end of its life cycle for reasons of Concurrent
EE R&M and LE studies and implementation of the recommended measures done periodically
during its operational life time with much lower capital cost.
(e) CEE R&M and LE will lessen the shut
down period of the unit with continual implementation of CEE R&M and LE periodically
minimizing extent and scope of major defects developing in the unit compared to
a longer shut down period sought by the implementing EPC Contractors, including
in some cases, extension of time, for various reasons specially the surprises and
unforeseen development, for completion.
(f) Incidences of breakdown of the unit that
take place due to serious defects and deficiencies developing in the unit which
are not noticeable during routine O&M of the plant and lack of in- depth technical
studies and implementation measures.
(g) Technology as available at the time of
Concurrent CEE R&M and LE can be availed and applied as CEE R&M and LE is
undertaken periodically and enables true and fair assessment of the unit performance
through Energy Audit and Condition Assessment studies and practical implementation
of the program for improvements and up-gradation of the unit. This is not so in
the case when the unit is taken up for EE R&M and LE after it outlived its life
cycle. Experience shows that operational, technical and performance data in such
cases is not readily available and, if available, not fully reliable which affect
authenticity and quality of studies and their recommendations.
(h) CEE R&M and LE periodically undertaken
will result in minimization of expenditure on routine O&M of the unit year after
year as the unit will continue to be maintained and run with greater operational
efficiency through periodical technological up-gradation and improvements of unit
and all its systems.
(i) CEE R&M and LE opens up new window
for development of newer technologies based on the experience gained through periodical
CEE R&M and LE with scope for newer employment opportunities.
(j) CEE R&M and LE also opens up scope
for gradual growth of indigenous consultancy, competency, capacity and capabilities
with increasing opportunities under CEE R&M and LE compared to EE R&M and
LE undertaken once on completion of life cycle of the unit. It is pertinent to note
that lack of experienced and technical competent consultants within the country
is one of the reasons in slowing down the implementation process of EE R&M and
LE of older power units.
(k) CEE R&M and LE will ensure maintaining
higher level operational efficiency of the unit throughout its normative Life Cycle
period and will continue with same level of efficiency thereafter at least up to
35-40 years beyond 25 years life cycle.. With further CEE R&M and LE measures
when the Unit completes 35-40 years, it is possible that the operational life of
the Unit may continue with assured efficiency up to 45-50 years.
(l) CEE R&M and LE will assure consistent
and continuous additional energy and revenue to the Utility resulting from its higher
level of operational efficiency with the periodical up-gradation and improvements
of its operational capacity.
(m) Several barriers that were identified from
time to time and considered responsible for delaying the implementation of EE R&M
and LE of Older Coal Based Thermal Power Plants will have no impact nor will affect
the suggested CEE R&M and LE Program.
1.1.4 The above stated logic and the need for
CEE R&M and LE also applies to Coal Based Thermal Power Units under various
stages of construction and new Units at various stages of processing. However, the
method of funding and implementation are different for each category...
1.2 CLASSIFICATION OF COAL BASEDTHERMAL POWER UNITS FOR THE PURPOSE OF CEE R&M AND LE.
Coal Based Thermal Power
Units in Operation.
|
S.
No.
|
Unit
Capacity (MW)
|
Life
Cycle completed up to 12th Plan (31.03.2017)
|
Units
in operation remaining to be completed beyond 12th Plan (31.03.2017)
|
|||
|
No.
|
Capacity
(MW)
|
Years
|
No.
|
Capacity
(MW)
|
||
|
1.
|
Below 100 MW
|
4
|
290
|
25
|
-
|
|
|
2.
|
100 -250 MW
|
17
|
3120
|
25
|
39
|
9122
|
|
3.
|
250 -500 MW
|
2
|
1000
|
25
|
6
|
3000
|
|
4.
|
500 MW and above
|
-
|
-
|
-
|
3
|
1800
|
|
|
Total
|
23
|
4410
|
25
|
48
|
13922
|
1.2.1.1
Details
are given in Annexure 1 and 1A of this paper. Figures in Annexure 1 and 1A are indicative
compiled figures based on website data and are subject to change.
1.2.1.2
As
will be seen from the above analysis, of the 71Units in operation of total capacity
of 18332MW, 23 Units with capacity of 4410MW will be completing their life cycle
at the end of the 12th Plan (2016-17) which are to be considered as addition
to 58 Units covered presently in the 12th Plan as stated in 1.4 above.
Funding of additional 23 Units is proposed in 1.11 above. The remaining 48 Units
of capacity of 13922MW are in various years of operation and will be completing
their life cycle subsequent to the 12th Plan period.
1.2.1.3
CEE
R&M and LE of remaining 48 Units in operation presently is proposed as below.
..
1.2.2 Eligibility Conditions
a.
Coal
Based Thermal Power Unit must be owned and operated by the State Power Utilities.
b.
Unit
should be in operation and should have completed operational period of not less
5 years from its COD
c.
Unit
should have been approved by CEA for inclusion under CEE R&M and LE Program.
d.
Utility
of the Unit should have fully repaid loan availed by it from the FIs against the
Unit
e.
Utility
must be agreeable to mortgage the assets of the Unit to FIs against the loan to
be availed for CEE R&M and LE.
f.
Utility
must also be agreeable to complete and comply with all the loan covenants and loan
documentation as may be specified by the FIs in the Letter of Sanction of Loan.
1.2.3 Method of Implementation
1.2.3.1
Break
up of Life Cycle of remaining 48 Units referred to in 2.2.1 above is as follows:
5 years and below
|
9
|
|
Above 5 years but below 10
years
|
19
|
|
Above 10 years but below15
years
|
Nil
|
|
Above 15 years but below20
years
|
9
|
|
Above 20 years and up to
25 years
|
11
|
|
Total
|
48
|
1.2.3.2
These
are classified Group-wise as under:
Group A 9 Units
Group B 19 Units
Group C 9 Units
Group D 11 Units
1.2.3.3
Debt
repayment status of loans availed by the utilities from the FIs is presumed to be
as below
Group A Loans fully repaid
Group B Loans fully repaid
Group C Loans fully repaid
Group D Loans yet to be fully repaid
1.2.3.4
37
Units which come in Group A, B and C may be considered under Concurrent EE R&M
and LE Program. 11 Units in D are to be considered under the above program as and
when the loan availed against each Unit is fully repaid to the FIs..
1.2.3.5
Total
estimated capital cost of CEE R&M and LE of each Unit should not exceed 40%
of prevailing EPC cost of new generating unit of indigenous origin for each of 37
Units under Group A, B and C considering the fact that the Utilities owning these
Units would have fully repaid loans to FIs availed against the Units and have short
to medium period for life cycle completion.
1.2.3.6
Total
estimated capital cost of CEE R&M and LE of each Unit should not exceed 30%
for each of 11 Units under Group D considering these Units are yet to repay loans
in full to FIs availed against the Units and would have become eligible for inclusion
under CEE R&M and LE Program soon after the Utility has repaid fully loans availed
from FIs against the Unit and have a longer life cycle to be completed.
1.2.3.7
Total
estimated capital cost referred to in (e) and (f) will be derived from the DPR of
each Unit approved by the Board of Directors of the Utilities.
1.2.3.8
CEE
R&M and LE of 37 Units in Group A, B and C will be implemented in the following
manner :
(a)
CEE
R&M and LE of 37 Units in operation, the life cycle completion period of which
is between 5 years and below and 20 years which have fully repaid their loans availed
from FIs against the Units may be taken up for implementation in four Blocks with
first Block of below 5 years, second Block of 5 years but below 10 years, third
Block of 10 but below 15 years and fourth Block of 15 but below 20 years..
(b)
CEE
R&M and LE of 11 Units in operation, the life cycle completion period of which
is between 20 years and 25 years which have not fully repaid their loans availed
from FIs against the Units may be taken up for implementation after the loan is
fully repaid in four Blocks from the date of repayment of final installment with
first Block of 5 -10 years, second Block of 11-15 years, third Block of 15-20 years
and fourth Block of 20-25 years.
1.2.3.9
Utilities
of 37 Units in Group A, B and C may initiate action for inviting Bids for selection
of CEE R&M and LE Consultant for Energy Audit, Condition Assessment, Review
and Examination of all the relevant Engineering and Technical aspects of the Unit
and preparation of Detailed Project Report.(DPR)..
Six months before the beginning of each
FYB a Consultant may be engaged for -
(a) Energy Audit and Condition Assessment as
well as overall operation efficiency and performance assessment.
(b) Submission of Detailed Project Report which
will be numbered for each FYB as First Bock DPR, Second Block DPR, Third Block DPR
and Fourth Block DPR.
(c) Recommending measures to be taken up for
up- gradation of the Unit and enhancement of its operational efficiency and on such
other action oriented matters as are considered relevant.
1.2.3.10 Utilities of 11 Units in Group C and D
may initiate action for inviting Bids for selection of CEE R&M and LE Consultant
for Energy Audit, Condition Assessment, Review and Examination of all the relevant
Engineering and Technical aspects of the Unit and preparation of Detailed Project
Report (DPR) at least one year in advance calculated backward from the due date
of repayment of last and final installment of loan to FIs availed against the Unit.
Before the expiry of six months of the
completion period of each Block a Consultant may be engaged for –
(a) Energy Audit and Condition Assessment as
well as overall operation efficiency and performance improvement
(b) Submission of Performance Report (PR) which
will be numbered for each completion period Block as First PR, Second PR, Third
PR, Fourth PR and Fifth PR
(c) Recommending measures to be taken up for
up- gradation of the Unit and enhancement of its operational efficiency and on such
other action oriented matters as are considered relevant.
1.2.4 Mode of Funding, Interest Payment and Repayment of Loan
1.2.4.1
Funding
may be on the basis of the Total Estimated Capital Ratio stated in 2.2.3.5 and
2.2.3.6.and the Total Estimated Capital Cost referred to therein will be as provided
in approved DPR.
(a) The terms and conditions of financing by
PFC/REC may be as follows:
|
1.2.4.2
Mode
|
Loan
|
|
1.
Loan Limit
|
(a)
Utilities of 37 Units which have fully repaid loans may
be considered eligible immediately to apply for loans for Concurrent EE R&M
and LE to PFC/REC equivalent to 80% of the estimated capital cost in 2.2.3.5 of each Unit.
(b)
Utilities of 11 Units which are yet to repay loan in full
availed against the Unit may be considered eligible to apply for loan for Concurrent
EE R&M and LE to PFC/REC as and when Utilities have repaid the loan in full
to FIs availed against the Unit, equivalent to 80% of the estimated capital cost
in 2.2.3.6 of each Unit.
(c)
Balance 20% of the estimated capital cost stated in (i)
and (ii) will be met by the Utilities from their own resources.
|
|
2.
Disbursement of sanctioned Loan
|
(a)
Loans sanctioned by PFC/ REC for each Unit referred to in
1 (a) above will be disbursed by PFC/ REC to the Utilities on compliance of the
loan covenants and completion of loan documentation in installments of 15% in
the First Block Year, 20% in the Second Block Year, 30% in the Third Block Year
and 35% in the Fourth Block Year.
(b)
Loans sanctioned by PFC/ REC for each Unit referred to in
1 (b) above will be disbursed by PFC/ REC to the Utilities on compliance of the
loan covenants and completion of loan documentation in installments of 15% in
the First Block Year, 20% in the Second Block Year, 30% in the Third Block Year
and 35% in the Fourth Block Year.
|
|
1.2.4.3
Opening of Multi Option Deposit (MOD) Account by the State
Power Utilities with their Bankers.
|
1.2.4.3.1
Funds received as per 3 (a) or (b) above will be invested
in Multi Option Deposit (MOD) Account by the State Power Utilities to be opened
with their Bankers after completing the procedure as required by the Bankers.
(a)
MOD will be maintained for each Unit Loan separately with
the amount to be deposited being equal to the amount of installment disbursed.
,
(b)
The interest on the amount deposited will be not less than
Term Deposit interest rate to enable the Utility to lessen, if not, offset its
interest liability to PFC/REC.
(c)
The amount will be invested within three days of the date
receipt from PFC/REC.
(d)
The period of deposit will be corresponding to the period
envisaged for completion of the Unit as per the DPR.
(e)
The State Power Utility may draw the funds from the MOD
according to its Financial Phasing Requirements prepared by the Utilities and
approved by their Board/Director (Finance).
(f)
Each drawl from the MOD will be authorized only after obtaining
the approval of GM (F) or Director (F) as per the internal systems and control
of the utility.
(g)
MOD system permits the Utility to make payment through Crossed
A/c Payee Not Negotiable Cheques to the Contractor implementing the Unit direct
according to the Schedule of Activities completed and subject to compliance of
other terms and conditions under the Terms of Payment specified in the Bidding
Documents. To that extent, the MOD will get reduced and the interest will be applicable
on that basis, however, the average interest earned need to be maintained at least
equal to Term Deposit Interest Rate.
|
|
5. Repayment Period
of Loan
|
10 years in equal half
yearly installments from COD of the Unit after completion of CEE R&M and LE
Works and commissioning of the Unit.
|
|
6. Grace
Period for Repayment of Line of Credit
|
PFC/REC may consider
approving Grace Period for repayment of Loan in years equal to the period envisaged
for completion of the Unit considering the intent of the Loan..
|
|
i. Rate of Interest (ROI)
|
(a)Concessional Interest
Rate as applicable to EE R&M and LE Loans.
(b)
Interest may be payable to PFC/REC Quarterly commencing
from the date of disbursement for the First Block Year referred to iii (a) or
iii (b) above, as the case may be..
(c)
Interest liability payable to PFC/REC will be met by the
Utility from out of the interest earned on MOD to the extent earned thereon.
|
|
8 Subsidization of differential
rate of interest between the interest charged by PFC/REC and interest earned on
the MOD maintained by the Utility with its Bankers, if becomes necessary..
|
MOP may subsidize the
Utility differential rate out of the funds under Restructured Accelerated Power
Development and Reform Program (R-APDRP)
|
|
9 Loan Processing Fee
|
PFC/REC may consider
waiving the Processing Fee considering the intent of Line of Credit.
|
|
10 Commitment Charges
|
PFC/REC may consider
waiving the Processing Fee considering the intent of Line of Credit.
|
1.2.5 Coal Based Thermal Power Units under various Stages of Construction
|
S. No.
|
Units Capacity
|
No. of Units
|
Total Capacity (MW)
|
|
1
|
Below 100 MW
|
2
|
100
|
|
2
|
100-250 MW
|
-
|
-
|
|
3
|
250-500 MW
|
4
|
1000
|
|
4
|
500 MW and above
|
13
|
7760
|
|
|
Total
|
19
|
8860
|
1.2.5.1 Details are given in Annexure. Figures
in Annexure 2 are indicative compiled figures based on website data and are subject
to change.
1.2.5.2 Above analysis ,show that 19 Units are
under various stages of Construction of total capacity of 8860MW. These are likely
to be commissioned in the 12th Plan.
1.2.6 Eligibility Conditions
Eligibility Conditions for
Coal Based Thermal Power Units under Construction will be the same as applicable
to Coal Based Thermal Power Units in Operation as given in paragraph 2.2.2 above.
1.2.7 Method of Implementation
Method of Implementation
of Coal Based Thermal Power Units under various stages of construction will be the
same as applicable to Coal Based Thermal Power Units in Operation as given in paragraph
2.2.3 above with the variation that their eligibility for consideration under CEE
R&M and LE will commence from the date of completion a period of 5 years from
the date of their COD in the order of their commissioning and COD.
1.2.8 Mode of Funding, Interest Payment and Repayment of Loan
Mode of funding,
interest payment and repayment of loan of Coal Based Thermal Power Units under construction
will be the same as applicable to Coal Based Thermal Power Units in operation as
given in paragraph 2.2.4 above with the variation that they will become eligible
for applying for CEE R&M and LE Loan after the completion of a period of 5 years
from the date their COD in the order of their commissioning and COD.
1.2.9 New Coal Based Thermal Power Units.
1.2.9.1 The number and names of New Coal Based
Thermal Units based on their current status clearances including Environmental Clearance
could not be ascertained and not included in this paper. However, it is assumed
that a number of Coal Based Thermal Power Units are in various stages of completion
of clearances, approvals, financing arrangements etc. and are in the pipeline for
initiation of construction. The Logic and the Need for inclusion of New Coal Based
Thermal Power Units under CEE R&M and LE is different compared to the Logic
and the Need for (a) Coal Based Thermal Power Units in Operation and (b) Coal Based
Thermal Power Units under construction discussed in detail above. The Logic and
the Need for coverage of New Coal Based Thermal Power Units under CEE R&M and
LE are briefly stated below:
1.2.9.2 The State Electricity Boards (SEBs) that
existed prior to their restructuring and the Generating Companies (GENCOs) created
by the States as result of restructuring had been carrying out routine Operation
and Maintenance (O&M) of the Units according to the funds allocated as revenue
expenditure under their Budget. This practice continues to be followed presently.
Major overhauling of few Units due to accident or for reasons of a serious nature
had been done by some of the SEBs but no SEB/GENCO had undertaken periodical Renovation
and Modernization and Life Extension( up-gradation) of the Units to enhance their
operational efficiency, up-rate capacity, generate additional energy and revenue
and to maintain reasonably good health of the Units as they started aging.. This
could be attributed to adequate funds not being available to the Utilities from
time to time for incurring capital expenditure for the Units for the above purpose.
.For want of periodical up-gradation, most of the Units continued to under- perform
with declining trend in the operational parameters and efficiency..
1.2.9.3 To wait for initiation of EE R&M and
LE for New Coal Based Thermal Units after they outlived their operational life cycle
but are capable of continuing their operation would have resulted in their operational
degradation and declining capacity utilization by the time of their life cycle completion
due to extensive and intensive damage to their major components necessitating substantially
higher level of capital expenditure investment. Such expenditure could be substantially
saved through CEE R&M and LE during their operational life time .itself. After
an Unit has completed five years of its operation from COD, if CEE R&M and LE
is inducted from the sixth year extending over its remaining life cycle, on a Five
Year Block (FYB) basis, status of functional capacity of major components can be
ascertained through appropriate studies and, based on such studies, measures to
restore /upgrade the Unit could be implemented.. This would enhance Unit’s operational
efficiency on a continual basis with its automatic life extension beyond its normative
life cycle
1.2.9.4 Ensuring availability of adequate funds
to the Utilities for meeting capital expenditure for CEE R&M and LE of New Coal
Based Thermal Power Unit in future during each FYB beginning from completion of
5 years from COD up to 10th Year (First Block,), 11th to 15th
Year (Second Block), 16th to 20th Year (Third Block) and 21st
to 25th Year (Fourth Block) would facilitate Unit to operate economically
and efficiently and eliminate the need for any comprehensive renovation and modernization
process at the end of 25 years. The Utilities, as earlier stated, had not been able
to adopt such an approach so far solely for want of required financial resources
and have compulsively taking up EE R&M after the Unit has outlived its life.
It needs to be appreciated that CEE R&M and LE would assure the Utilities to
maintain and operate the Unit with periodical up-gradation with newest available
technology in each FYB and availability of the Unit with increasing generating capacity
and regular revenue flow all the time and would save longer time span of 3-5 years
for completion of EE R&M and LE presently being undertaken for older Units with
several uncertainties and unforeseen developments unfolding on completion of EE
R&M and LE..
1.2.9.5 Estimated Capital Cost of the future New
Coal Based Thermal Power Projects may include estimated cost of identifiable components
of capital nature for meeting capital expenditure of CEE R&M and LE in percentage
terms of the total estimated cost of the Project. Total cost for the capital expenditure
of CEE R&M could represent 30% of the total estimated cost of the Project. The
cost so included for CEE R&M and LE in the total estimated Project cost may
be allocated in equal proportion to each new Unit Capacity according to the number
of Units envisaged under the Project. This is explained by way of an example below:
1.2.9.6 Assuming that
(a) Project comprises 3x500 MW Capacity = 1500
MW
(b) Current cost per/MW = INR 50m
(c) Total estimated Project Cost = 1500x50=
INR 75000m
(d) Earmarking 30% of (c) for CEE R&M =
INR 75000x30/100= INR 22500m
(e) Allocation for each Unit = 22500/3 = INR
7500m = 33.33% for each New Unit.
(f) Total estimated Project cost including
provision for CEE R&M and LE = 75000+22500=INR 97500m
1.2.9.7 The provision of INR 7500m or 33.33% of
30% of the total estimated Project cost may be earmarked for FYB @ 5% or INR 1125m
for the First Block, 7.5% or INR 1688m for the Second Block, 9.5% or INR 2138m for
the Third Block and 11.33% or INR 2549m for the Fourth Block of each new Unit. This
is a provision for each year and the actual utilization and application of the fund
so available will, however, be based on detailed study and assessment of the capital
components required for CEE R&M and LE in each year of each 5 year block .and
the capital expenditure will be incurred accordingly from out of the amounts earmarked
for each Unit as stated above..
1.2.9.8 Comprehensive Energy Efficient R&M
has been taken up for Bandel TPS (WBPDCL) at the total estimated cost of INR 4725m,
Koradi TPS (MAHAGENCO) at the total estimated cost of INR 4860m and Nashik TPS (MAHAGENCO)
at the total estimated cost of INR 4815m, the average cost of which works out to
INR 4800m. For setting up a greenfieid 210 MW TPP, the estimated cost at present
per MW cost of INR 45m, will be INR 9450m. The average cost of INR 4800m of the
above three projects compared to the green field cost of 210 MW TPP of INR 9450m,
works out to 50.75% of the estimated cost of the green field project.
1.2.9.9 The proposed provisioning of INR 7500m
towards CEE R&M and LE for each new Unit represents an increase of 56.25% or
an average of 14.06% for each FYB or 2.81% per annum, over the average cost of EE
R&M and LE of INR 4800m as worked out above for EE R&M and LE of three Older
Units undertaken which have outlived their life cycle. It may be argued that it
is more economical to undertake EE R&M and LE of an Older Unit on completion
of its life cycle rather than taking up CEE R&M and LE concurrently for each
FYB from the 6th year of COD considering increase in the cost in the latter case
compared to the former case. This argument does not hold good for the following
reasons:
(a) The average cost of EE R&M and LE of
Older Units now undertaken is an one time investment cost but unsure of the additional
cost on account of escalation in the cost of equipment and material considered due
to delay in its implementation because of uncertainty of assumptions as well as
further additional cost that may become necessary on account of surprises and unforeseen
developments during implementation. This is so because as of now no EE R&M and
LE Older Unit Project has been completed and the final outcome of the capital cost
is unknown.
(b) The provisioning considered for CEE R&M
and LE in the total estimated cost of a new Project assumes an annual escalation
of 2.81% over the remaining life cycle of 20 years from 6th year of COD
which is reasonable, detailed CEE R&M and LE studies are undertaken before the
start of a FYB of each Unit which enables identification and pinpointing the precise
deficiencies in the operation process of the Unit, recommends specific measures
including replacement of components with available new technology for sustaining,
if not increasing, the operational efficiency of the Unit for each FYB. This does
not involve any surprises or unforeseen developments and the need for undertaking
EE R&M and LE on completion of the life cycle of Unit. By reason of continual
up-gradation of the Unit based on techno-commercial-financial studies and implementation
of measures recommended therein using the funds from the provisioning made in the
total estimated project cost at the beginning itself, the Unit is assured of performing
at higher operational efficiency level all through it remaining life cycle and further
increase of its life cycle for the next 10-15 years.
(c) It may be mentioned that the in case of
EE R&M and LE of Unit after it outlived its life completion necessitates approval
of the regulatory authority for each Unit with need for greater and sound justification
for the additional capital cost proposed excluding the surprises and unforeseen
development that may occur during actual implementation whereas in the case of CEE
R&M and LE, the approval of regulatory authority is needed one time for provisioning
of cost of CEE R&M and LE as Deferred Capital Expenditure (DCE) covering all
the Units capacity included in the Project and such expenditure does not affect
the financial results and tariff at the start of COD but only as and when the expenditure
is incurred from out of the provision of DCE is actually incurred in each FYB of
the Unit based on the detailed studies. It may also be possible that the actual
expenditure incurred in the FYB may be less than the provision resulting in savings
to the Utility.
(d) It may also be mentioned that CEE R&M
and LE proposed for the Units (a) in operation, (b) under various stages of construction
and (c) new projects in the pipeline, if introduced and implemented in each FYB
will ensure availability of the Unit on regular and uninterrupted basis which will,
in turn, help availability of sustained and additional energy generation as a result
of regular studies and up-gradation with newer technology undertaken on performance
and operational efficiency parameters of the Unit in each FYB and is expected to
make up peak and energy deficit to a substantial extent which is the need of the
hour.
1.2.9.10 The 30% capital expenditure proposed for
inclusion in the total estimated cost of a new Project as addition to the estimated
cost of the Project assumes the character of “Deferred Capital Expenditure (DCE)”
to be incurred for CEE R&M and LE of the new Unit in each FYB after completion
of 5 year period from the date of its COD. Its utilization in the accounting method
of the Utility is reflected when that expenditure
is occurred in each FYB, capitalized in the FY in which CEE R&M and LE is completed
and thereafter charged to Depreciation in the Profit & Loss Account of the Utility
in each FY over the life cycle of the Unit according to its normal accounting policy..
Being a provision in the total estimated cost of the Project with its deferred use
from the 6th year of COD for each FYB thereafter, DCE is not treated as part of
the total estimated cost of the new Project for working the financials of the Project
including the Tariff and IRR and, accordingly, will not have any impact on the financial
viability and economic justification of the new Project.
1.2.9.11 Thus the provisioning of 30% of the estimated
cost of Project cost for the purpose of meeting the cost of CEE R&M and LE on
FYB basis beginning from 6th year of COD for the entire life cycle of the new thermal
power project suggested above is to be regarded as in order and justifiable.
1.2.9.12 CEA Guidelines on R&M and LE (October, 2009)
provide for the cost of LE and U works of Older Units limited to 50% of the EPC
cost of new generating unit of indigenous origin whereas the suggested percentage is 30% of the
total estimated cost of the Project. Limit of 50% of the EPC cost of new generating
unit of indigenous origin for LE and U works
of Older Units appears to be based on the assumption that EE R&M and LE is intended
to be undertaken for Unit that has outlived its life cycle and would need a higher
level of investment. A limit of 30% is proposed for CEE R&M and LE as mentioned
above keeping in mind that the capital expenditure is assigned in ascending percentages
for CEE R&M and LE for every FYB, the Unit continues to be maintained in good
and technical healthy condition with sustained if not increasing operational efficiency
and would not involve any EE R&M and LE on completion of its useful life cycle
and no additional capital expenditure is needed for the Unit at that point of time.
Ascending percentage order is considered to correspond to the need for a higher
capital expenditure with the aging of the Unit
1.2.9.13 The underlying essence of CEE R&M and
LE through Deferred Capital Expenditure (DCE) is summarized below:
(a) The capital expenditure (CAPEX) includes
expenses like renovations or equipment up gradation of equipment which adds value
to the assets of a company. Moreover, the capital expenditures generally depreciate
with time and feature a long life. In accounting terms, expenditure is considered
as a capital expenditure if the asset is a recently purchased capital asset or an
investment that is helpful in improving the useful life of an existing capital asset.
Moreover, if expenditure is a capital expense, it should be essentially capitalized,
which requires the company to increase the cost of expenditure over the assets’
useful life.
(b) Only expenditure that increases the future benefits
from the existing asset beyond its previously assessed standard of performance is
included in the gross book value, e.g., an increase in capacity. The cost of an
addition or extension to an existing asset which is of a capital nature and which
becomes an integral part of the existing asset is usually added to its gross book
value (ICAI Accounting Standard (AS) 10).
(c) Machinery spares of the nature of capital
spares/insurance spares should be capitalized separately at the time of their purchase
whether procured at the time of purchase of the fixed asset concerned or subsequently.
The total cost of such capital spares/insurance spares should be allocated on a
systematic basis over a period not exceeding the useful life of the principal item,
i.e. the fixed asset to which they relate. (ICAI Accounting Standards Interpretation
(ASI) 2)
(d) Annual funding for facilities operations
and maintenance is expected to accommodate major maintenance and thereby compensate
for the aging process of facilities and equipment. Separate funding for functional
improvements in operating budgets is necessary to protect funding of capital renewal.
Major maintenance is typically treated as a residual category after budgeting for
plant administration, building and equipment maintenance, custodial services, utilities,
and grounds maintenance. The residual treatment often leaving major maintenance
and functional improvements unfunded has proven to be inadequate to meet plant needs
and is how most equipments reached their current levels of deferred maintenance.
The preferred approach is to establish an appropriate level of funding for major
maintenance and capital renewal in the operating budget to prevent continued obsolescence
of facilities and equipment. (Capital Renewal and Deferred Maintenance Programs
by Harvey Kaiser)
(e) An appropriate level of funding established
at the beginning of a comprehensive facilities funding program may have to include
catch-up costs (Capital Renewal and Deferred Maintenance Programs by Harvey Kaiser)
(f) Deferred maintenance projects for mechanical
and electrical systems, utilities infrastructure, or central energy plants can be
treated as unique capital renewal projects for energy conservation. Facilities audits
have shown that 40 to 50 percent of deferred maintenance exists in these categories.
The rationale that energy conservation will result from these projects is based
on cost-benefit analyses identifying payback periods. Thus an investment in energy
conservation can be considered self-financing.( Capital Renewal and Deferred Maintenance
Programs by Harvey Kaiser)
(g) A five-year capital budget plan provides
a level of confidence for the utility in the facilities management by regularly
reviewing overall capital requirements. A level of capital requirements is established
in long-range budget base planning, offering flexibility for emergencies or special
situations that cannot be anticipated. (Capital Renewal and Deferred Maintenance
Programs by Harvey Kaiser)
(h) View a facility as a collection of components
and systems .The deterioration of a component can cause breakdowns in other parts
of a system. Evaluation of a repeated maintenance problem should consider the system
nature of facilities. Facilities deterioration can be offset by maintenance management
staff pooling knowledge of unsatisfactory conditions that are developing into major
problems (Capital Renewal and Deferred Maintenance Programs by Harvey Kaiser)
1.2.10 Eligibility Conditions
(a) Future New Coal Based Thermal Power Unit
must be owned by the State Power Utilities.
(b) Utility should have obtained all the Statutory
and Non- Statutory Clearances, Consents, Approvals, Permits etc. for the setting
up of the Project as per the requirements of the Policies of the Central/ State
Governments for developing the New Power Project including Clearances from MOEF
(c) Utility should have completed the Detailed
Project Report (DPR) covering all aspects of Techno-Commercial-Financial and the
status of fulfillment of the requirements of obtaining Statutory and Non- Statutory
Clearances, Consents, Approvals, Permits etc. of the Project through reputed Consultants
with full justification on the Technical Feasibility and Financial Viability of
the Project.
(d) In DPR, a separate Section titled “CEE
R&M and LE” will be provided incorporating therein the main policy features,
approach and methodology of its implementation and the manner of drawl of funds
and their utilization for the purpose with respect to each Unit of the Project for
which DEP is prepared, according to the Policy Guidelines issued by CEA based on
this Draft Concept Paper as approved by CEA.
(e) Utility should have obtained approval of
its Board of Directors to the DPR including approval to the Equity to be provided
through internal Sources and Debt to be secured from the FIs.
(f) Unit should have achieved its Financial
Closure and has become eligible for consideration by the FIs for financing.
(g) Utility of the Unit should have submitted
its Loan Application to the FI for sanction of loan for the Unit.
(h) Utility must be agreeable to mortgage the
assets of the Unit to FIs against the loan to be availed for CEE R&M and LE.
(i) Utility must also be agreeable to complete
and comply with all the loan covenants and loan documentation as may be specified
by the FIs in the Letter of Sanction of Loan.
1.2.11 Mode of Funding, Interest Payment and Repayment of Loan for CEE R&M
and LE of New Coal Based Thermal Power Projects (Units)
(a) The terms and conditions of financing by
PFC/REC may be as follows:
|
1.
Source
|
Indian FIs/ Multi-lateral
/Bi- Lateral FIs
|
|
2.
Mode
|
Loan for the New Project + Provision for CEE
R&M and LE
|
|
3.
Loan Limit
|
Estimated
Project Cost all inclusive + a provision limited to 30% of the estimated Project
Cost as “Deferred Capital Expenditure” for “Concurrent Energy Efficiency R&M
and LE (CEE R&M and LE) subject to Debt : Equity Ratio as specified in the
DPR or as applicable according Lending Policies of FI.
|
|
4.
Sanction of Loan
|
Estimated
Project Cost all inclusive + a provision limited to 30% of the estimated Project
Cost as “Deferred Capital Expenditure” for “Concurrent Energy Efficiency R&M
and LE (CEE R&M and LE) subject to Debt : Equity Ratio as specified in the
DPR or as applicable according Lending Policies of FI.
|
|
5.
Disbursement of Loan
|
a.
Project Loan (excluding CEE R&M and LE provision) may
be released in installments according to phasing of expenditure and procurement
plan by the Borrower subject to fulfillment by the Borrower all the loan conditions,
covenants and loan documentation governing the disbursement of Project Loan.
b.
b.
Loan provision limited to 30% of the total loan sanctioned
and earmarked for CEE R&M and LE of Units covered under the Project may be
released in lump sum at the time of release of First Installment of the loan to
the Borrower subject to fulfillment by the Borrower such additional loan conditions,
covenants and documents/undertakings as may be deemed appropriate and prescribed
by the FI in the Letter of Sanction of Loan, in addition to the fulfillment of
the normal governing conditions, covenants and loan documentation for the Project
Loan.
.
c.
FI may specify as a Pre-condition in the Letter of Sanction
of Loan that the disbursed amount of CEE R&M and LE loan component in lump
sum to the Borrower shall be subject to the Borrower opening Multi Option Deposit
(MOD) Account with its Banker (s) for each Unit of Project in the following manner:
“XYZ Borrower
– CEE R&M and LE for Unit No._____of _____________Coal Based Thermal Power
Station at _____________”
and deposit
the amount so received into the said MOD A/c in equal proportion for each Unit
within three days of receipt of the lump sum amount aforesaid and will send a
confirmation in writing to the FI of having complied with the above requirement
along with an Undertaking on a Non-judicial paper of appropriate value duly signed
by an authorized officer of the Borrower to the effect that the amount deposited
in each of the said MOD A/c shall be utilized by the Borrower solely and exclusively
for the Concurrent Energy Efficiency R&M and LE of the Unit during the period
of the Life Cycle of the Unit within seven days from the date of deposit of the
amount in the MOD A/c of each Unit.
|
|
6.
Operation of Multi Option Deposit (MOD) Account.
|
(a)
The interest on the amount deposited will be not less than
Term Deposit interest rate to enable the Utility to lessen, if not, offset its
interest liability to FI.
(b)
The period of MOD A/c will be initially for ten (10) years
from the date .of its opening and deposit
of the amount to be extended for next ten (10) years and thereafter for five (5)
years covering the Life Cycle of 25 years of the Unit.
(c)
The Borrower will draw the funds from the MOD A/c in the
following manner for utilizing for CEE R&M and LE of the Unit named in the
above A/c:
(d)
5% of the deposit in the First Five Year Block beginning
from the 6th Year and ending at the 10th Year .from the
date of COD; or the actual expenditure incurred on account of CEE R&M and
LE during that period.
(e)
7.5% of the deposit
in the Second Five Year Block beginning from the 11th Year and ending
at the 15th Year from the date of COD;.
(f)
9.5% of the deposit in the Third Five Year Block beginning
from the 16th Year and ending at the 20th Year from the
date of COD; and
(g)
11.33% of the deposit in the Fourth Five Year Block beginning
from the 21st Year and ending at the 25th Year from the
date of COD.
(h)
For the purpose of drawl of the funds from the MOD A/c in
the manner as aforesaid shall be subject to fulfillment of the following conditions:
(i)
Each drawl from each Unit MOD A/c will be authorized only
after obtaining the approval of GM (F) or Director (F) as per the internal systems
and control of the Borrower.
(ii)
In case the actual expenditure on CEE R&M and LE in
a particular Five Year Block (FYB) is less than the specified percentage for that
FYB, the drawl from the Unit MOD A/c will be limited to the actual expenditure.
(iii)
The CEE R&M and LE expenditure in a particular a particular
FYB is greater than the specified percentage, the difference may be met from the
deposit in such a manner that the total expenditure on CEE R&M and LE up to
the Fourth Five Year Block is within the total amount of the deposit.
(iv)
If the total expenditure on CEE R&M and LE exceeds the
deposit at the end of the Fourth Five Year Block or at the end of any earlier
Five Year Block, the excess expenditure over the deposit will be met by the Borrower
from its own resources.
(v)
The average interest earned on the deposit in the Unit Mod
A/c will not be less than the Term Deposit interest rate in order to lessen interest
liability burden of the Borrower to the FI on CEE R&M and LE loan component.
(vi)
The interest earned on the Unit MOD A/c will used by the
Borrower solely for meeting its periodical interest liability to the FI.
(vii)
In case interest earned on the Unit MOD A/c falls short
of meeting the periodical interest liability of the Borrower to the FI, such shortfall
amount will be met by the Borrower from its own resources or through subsidization
of differential interest amount if made available by MOP under the funds earmarked
for R&M and LE under Restructured Accelerated Power Development and Reform
Program (R-APDRP).
|
|
7.
Rate of Interest (ROI)
|
a)
Concessional Interest Rate as applicable to EE R&M and
LE Loans.
b)
Interest may be payable to FI Quarterly or Semi-annually
as may be specified by the FI...
|
|
8.
Subsidization of differential rate of interest between the
interest charged by FI and interest earned on the Unit MOD A/c to the Borrower
if its interest liability to the FI is higher than the periodical interest earned
by it ..on Unit MOD A/c.
|
MOP may consider subsidizing
the Borrower differential rate out of the funds earmarked for R&M and LE under
(R-APDRP)
|
|
9.
Repayment Period of Loan
|
12 years in equal half
yearly installments considering the intent of the loan..
|
|
10.
Grace Period for Repayment of Loan
|
One year commencing from date of COD considering
the intent of the Loan..
|
|
11.
Loan Processing Fee
|
FI may consider
waiver of Processing Fee considering the intent of the loan.
|
|
12.
Commitment Charges
|
FI may consider
waiver of Commitment Charges on undrawn portion of the loan sanctioned considering
the intent of loan.
|
ANNEXURE - I
UNIT CAPACITY-WISE
COAL BASED THERMAL POWER UNITS IN OPERATION WITH TOTAL PERIOD OF OPERATION AND THEIR
REMAINING LIFE CYCLE
|
S. No.
|
Unit Capacity (MW)
|
State
|
Total Period of Operation till the end of 12th
Plan (31.3.2017) from the date of Commissioning
|
Remaining Life Cycle Period of Units (Life
Cycle assumed as 25 years
|
|
1.
|
Below 100 MW
|
|
|
|
|
|
2x70, 2x75
|
Gujarat
|
25
|
-
|
|
2.
|
100-250 MW
|
|
|
|
|
|
1x110
|
Rajasthan
|
4
|
21
|
|
|
2x120
Unit 1
Unit 2
|
Gujarat
|
19
25
|
6
-
|
|
|
1x250
|
Madhya Pradesh
|
4
|
21
|
|
|
1x250
|
Uttar Pradesh
|
5
|
20
|
|
|
1x250
|
Uttar Pradesh
|
5
|
20
|
|
|
2x250
|
Rajasthan
|
7
|
18
|
|
|
2x250
|
Chhattisgarh
|
10
|
15
|
|
|
2x250
|
Delhi
|
5
|
20
|
|
|
3x210
|
Tamil Nadu
|
23
|
2
|
|
|
4x210
Unit -1
Unit -2
Unit -3
Unit- 4
|
Chhattisgarh
|
34
33
32
31
|
-
-
-
-
|
|
|
4x210
Unit- 1
Unit- 2
Unit- 3
Unit- 4
|
Andhra Pradesh
|
23
22
10
10
|
2
3
15
15
|
|
|
2x210
2x250
|
Punjab
|
19
|
6
|
|
|
2x250
Stage- V
Stage- V
|
Andhra Pradesh
|
20
19
|
5
6
|
|
|
5x210
|
West Bengal
|
18
|
7
|
|
|
4x210
|
Madhya Pradesh
|
25
|
-
|
|
|
4x120
|
Maharashtra
|
25
|
-
|
|
|
6x250
|
Rajasthan
|
19
|
6
|
|
|
2x351
|
Gujarat
|
4
|
21
|
|
|
4x210
2x250
|
West Bengal
|
21
|
4
|
|
3.
|
250-500 MW
|
|
|
|
|
|
1x500
Stage VI
|
Andhra Pradesh
|
6
|
19
|
|
|
1x500
|
Madhya Pradesh
|
25
|
-
|
|
|
1x500
|
Maharashtra
|
25
|
-
|
|
|
1x500
|
Andhra Pradesh
|
8
|
17
|
|
|
1x500
|
Chhattisgarh
|
4
|
21
|
|
|
1x500
|
Gujarat
|
4
|
21
|
|
|
2x500
|
West Bengal
|
21
|
4
|
|
4.
|
500 MW and above
|
|
|
|
|
|
1x600
|
Haryana
|
7
|
18
|
|
|
1x600
|
Tamil Nadu
|
5
|
20
|
|
|
1x600
|
Tamil Nadu
|
4
|
21
|
Figures in Annexure 2 are indicative compiled
figures based on website data and are subject to change.
ANNEXURE - IA
|
|
NAME-WISE COAL BASED THERMAL
POWER UNITS IN OPERATION
|
||||||||
|
S.No.
|
Name
|
Unit Size
|
Capacity (MW)
|
State
|
Commission Date
|
Total Period of Operation
of Plant till end of 12th Plan (2016-17)
|
Remaining Life Cycle period
of Plant (life cycle period assumed 25 years of operation)
|
Total Period of Operation
of Plant till end of 13th Plan (2021-22)
|
Remaining Life Cycle period
of Plant (life cycle period assumed 25 years of operation)
|
|
1
|
2
|
3
|
4
|
5
|
6
|
7
|
8
|
9
|
10
|
|
|
|
|
|
|
|
|
|
|
|
|
1
|
Ramgarh CCPP Extn
|
1x110
|
110
|
Rajasthan
|
GT - 2013
|
4
|
21
|
9
|
16
|
|
2
|
Dhuvaran TPS
|
2x110
|
220
|
Gujarat
|
NA
|
NA
|
NA
|
NA
|
NA
|
|
3
|
Sikka TPS
|
2x120
|
240
|
Gujarat
|
Unit 1 - 1998
|
19
|
6
|
24
|
1
|
|
|
|
|
|
|
Unit 2 - 1993
|
24
|
1
|
25 years completing in
2018
|
NA
|
|
4
|
Akrimota TPS
|
2x125
|
250
|
Gujarat
|
NA
|
NA
|
NA
|
NA
|
NA
|
|
5
|
Satpura TPS Extn
|
1x250
|
250
|
Madhya Pradesh
|
Unit 10 - 2013
|
4
|
21
|
9
|
16
|
|
6
|
Harduaganj
|
1x250
|
250
|
Uttar Pradesh
|
Unit -9 - 2012
|
5
|
20
|
10
|
15
|
|
7
|
Parichha Extn
|
1x250
|
250
|
Uttar Pradesh
|
Unit - 5 - 2012
|
5
|
20
|
10
|
15
|
|
8
|
Kutch TPS
|
2x70, 2x75
|
290
|
Gujarat
|
1990
|
25 years completing in
2015
|
NA
|
25 years completing in
2015
|
NA
|
|
9
|
Bhawendra Singh Deo TPS
|
4x50, 2x120
|
440
|
Chhattisgarh
|
NA
|
NA
|
NA
|
NA
|
NA
|
|
10
|
Chhabra TPS
|
2x250
|
500
|
Rajasthan
|
2010
|
7
|
18
|
12
|
13
|
|
11
|
Surat TPS
|
4x125
|
500
|
Gujarat
|
NA
|
NA
|
NA
|
NA
|
NA
|
|
12
|
Dr. Shyama Prasad Mukherjee
TPS
|
2x250
|
500
|
Chhattisgarh
|
2007
|
10
|
15
|
15
|
10
|
|
13
|
Kakatiya TPS
|
1x500
|
500
|
Andhra Pradesh
|
2009
|
8
|
17
|
13
|
12
|
|
14
|
Korba West ST-III
|
1x500
|
500
|
Chhattisgarh
|
Unit 5- 2013
|
4
|
21
|
9
|
16
|
|
15
|
Ukai TPP Extn
|
1x500
|
500
|
Gujarat
|
Unit -6 - 2013
|
4
|
21
|
9
|
16
|
|
16
|
Pragati CCGT- III
|
GT 3 - 250, GT4 - 250
|
500
|
Delhi
|
GT-3 -2012
|
5
|
20
|
10
|
15
|
|
|
|
|
|
|
GT-4 - 2013
|
4
|
21
|
9
|
16
|
|
17
|
Rajiv Gandhi TPS
|
1x600
|
600
|
Haryana
|
2010
|
7
|
18
|
12
|
13
|
|
18
|
Mettur TPP Extn
|
1x600
|
600
|
Tamil Nadu
|
Unit 1- 2012
|
5
|
20
|
10
|
15
|
|
19
|
North Chennai Extn
|
600
|
600
|
Tamil Nadu
|
Unit 2 - 2013
|
4
|
21
|
9
|
16
|
|
20
|
North Chennai TPS
|
3x210
|
630
|
Tamil Nadu
|
1994
|
23
|
2
|
25 years completing in
2019
|
NA
|
|
21
|
Pipavav CCPP
|
Block 1- 351, Block 2-
351
|
702
|
Gujarat
|
Block 1- 2013
|
4
|
21
|
9
|
16
|
|
|
|
|
|
|
Block -2 - 2013
|
4
|
21
|
9
|
16
|
|
22
|
Budge Budge TPS
|
3x250
|
750
|
West Bengal
|
NA
|
NA
|
NA
|
NA
|
NA
|
|
23
|
Korba West Hasdeo TPS
|
4x210
|
840
|
Chhattisgarh
|
Unit I - 1983
|
25 years completing in
2008
|
NA
|
25 years completing in
2008
|
NA
|
|
|
|
|
|
|
Unit 2 -1984
|
25 years completing in
2009
|
NA
|
25 years completing in
2009
|
NA
|
|
|
|
|
|
|
Unit 3 -1985
|
25 years completing in
2010
|
NA
|
25 years completing in
2010
|
NA
|
|
|
|
|
|
|
Unit 4 -1986
|
25 years completing in
2011
|
NA
|
25 years completing in
2011
|
NA
|
|
24
|
Rayalseema TPS
|
4x210
|
840
|
Andhra Pradesh
|
Unit 1- 1994
|
23
|
2
|
25 years completing in
2019
|
NA
|
|
|
|
|
|
|
Unit 2- 1995
|
22
|
3
|
25 years completing in
2020
|
NA
|
|
|
|
|
|
|
Unit 3 - 2007
|
10
|
15
|
15
|
10
|
|
|
|
|
|
|
Unit 4- 2007
|
10
|
15
|
15
|
10
|
|
25
|
Guru Hargobind TPS
|
2x210, 2x250
|
920
|
Punjab
|
1998
|
19
|
6
|
24
|
1
|
|
26
|
IB TPP
|
8x 120
|
960
|
Odisha
|
NA
|
NA
|
NA
|
NA
|
NA
|
|
27
|
Kothagudem TPS
|
2x250,1x500
|
1000
|
Andhra Pradesh
|
Stage V- 1997
|
20
|
5
|
25
|
Nil
|
|
|
|
|
|
|
Stage V - 1998
|
19
|
6
|
24
|
1
|
|
|
|
|
|
|
Stage VI - 2011
|
6
|
19
|
11
|
14
|
|
28
|
Bakreshwar TPS
|
5x210
|
1050
|
West Bengal
|
1999
|
18
|
7
|
23
|
2
|
|
29
|
Chandrapura TPS
|
3x130, 3x120, 2x250
|
1250
|
Jharkhand
|
NA
|
NA
|
NA
|
NA
|
NA
|
|
30
|
Sanjay Gandhi TPS
|
4x210, 1x500
|
1340
|
Madhya Pradesh
|
1993
|
24
|
1
|
25 years competing in 2018
|
NA
|
|
31
|
Khaperkheda TPS
|
4x120,1x500
|
1340
|
Maharashtra
|
Unit 1- 1989
|
25 years completing in
2014
|
NA
|
25 years completing in
2014
|
NA
|
|
|
|
|
|
|
Unit 2- 1990
|
25 years completing in
2015
|
NA
|
25 years completing in
2015
|
NA
|
|
|
|
|
|
|
Unit 3- 2000
|
17
|
8
|
22
|
3
|
|
32
|
Suratgarh STPS
|
6x250
|
1500
|
Rajasthan
|
1998
|
19
|
6
|
24
|
1
|
|
33
|
Mejia TPS
|
4x210, 2x250, 2x500
|
2340
|
West Bengal
|
1996
|
21
|
4
|
25 years completing in
2021
|
NA
|
|
34
|
Amravati
|
10x270
|
2700
|
Maharashtra
|
NA
|
NA
|
NA
|
NA
|
NA
|
|
Total Capacity
|
25762
|
||||||||
Figures
in Annexure 2 are indicative compiled figures based on website data and are subject
to change.
Annexure - II
|
UNIT CAPACITY-WISE COAL
BASED THERMAL POWER UNITS UNDER CONSTRUCTION
|
|||||
|
S.No.
|
No. of Units
|
Unit Capacity
|
Total Capacity
|
State
|
Implementing Agency
|
|
|
|
(MW)
|
(MW)
|
|
|
|
1
|
Below 100 MW
|
||||
|
|
1
|
30
|
30
|
Assam
|
APGCL
|
|
|
1
|
70
|
70
|
Assam
|
APGCL
|
|
2
|
100-250 MW
|
||||
|
|
Nil
|
|
|
|
|
|
3
|
250-500 MW
|
||||
|
|
1
|
250
|
250
|
Gujarat
|
GSECL
|
|
|
1
|
250
|
250
|
Maharashtra
|
MSPGCL
|
|
|
2
|
250
|
500
|
Rajasthan
|
RRVUNL
|
|
4
|
500 MW and above
|
||||
|
|
2
|
500
|
1000
|
Chhattisgarh
|
CSPGCL
|
|
|
1
|
500
|
500
|
Maharashtra
|
MSPGCL
|
|
|
2
|
500
|
1000
|
Uttar Pradesh
|
URVUNL
|
|
|
2
|
600
|
1200
|
Maharashtra
|
MPGENCO
|
|
|
1
|
600
|
600
|
Rajasthan
|
RRVUNL
|
|
|
1
|
600
|
600
|
Tamil Nadu
|
TNEB
|
|
|
1
|
600
|
600
|
Andhra Pradesh
|
APGENCO
|
|
|
1
|
660
|
660
|
Maharashtra
|
MSPGCL
|
|
|
2
|
800
|
1600
|
Andhra Pradesh
|
APPDL
|
|
Total
|
19
|
|
8860
|
|
|
|
Figures given in the statement are indicative
compiled figures based on Website Data and are subject to change
|
|||||
