Contracting for Power Purchase
Transcript of Contracting for Power Purchase
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Contracting for power purchase-Ensuring a fair
deal for the private investor as well as the power
purchaser
Lata Chakravarthy
Faculty Member
ICFAI Business School
Bangalore
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Objective of study
To identify best practices in power contracting to
encourage more private sector participation in
power generation.
To identify scope for reduction in cost of power
purchased from existing IPPs, by analyzing the
various fixed and variable components of purchase
cost and their impact on total tariff.
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Scope of study
Study covers the following IPPs whose PPAs
were available in public domain and which are
operating in South India:
1. GVK Power Corporation Ltd.
2. Spectrum Power Generation Ltd.
3. Kondapalli Power Corporation Ltd.
4. Madurai (Balaji) Power Corporation Ltd.
5. Tanir Bavi Power Corporation Ltd.
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Methodology
The basis for computing the fixed costs, variable
costs and incentives as laid out in the Power
Purchase Agreements (PPAs) were compared
and analyzed.
Terms of PPA which were amended/renegotiated
were studied to see the impact on tariff.
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Particulars GVK Spectrum Kondapalli Balaji Tanir
bavi
Project
awarded
through
MoU route MoU route Bid route MoU route Bid route
CompletedCapital cost
Rs.1025cr.
Rs.972.60cr.
Rs.1112 cr. Rs.429.03 cr. Rs.880 cr.
Installed
Capacity in
MW
216.824 208 368.144 106 220
Capital cost per
MW
Rs.4.73 cr. Rs.4.68 cr. Rs.3.02 cr. Rs.4.05 cr Rs.4 cr.
Term of PPA 18 years 18 years 15 years 15 years 7 years
Primary Fuel Gas Gas Gas (switched
over from
naphtha
In Sep 2002).
LSFO Naphtha
Commercial
Operation Date
June 1997 April 1998 October 2000 September
2001
July
2001
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Components of fixed charge in MOU projects
Interest on term loans
Interest on working capital
Depreciation
Return on Equity
Insurance 1% of capital cost
O&M expenses of 2% of capital cost
Foreign exchange variation on interest, debtrepayment and Return on Equity
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Components of fixed charge in bid route projects
Foreign Debt Service Charge (typicallyquoted in $ per kwh) towards,
Payment of interest on foreign currency loans
Repayment of foreign currency loans
Return on foreign equity Other Fixed Charge (typically quoted in Rs.
per kwh) towards,
Payment of interest on rupee loans
Repayment of rupee loans Return on rupee equity
O&M and insurance charges
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Comparison of price risk to utility in the two methods of
calculating fixed cost
MoU cases Risk of increase in capital cost after signing of PPA (Tariff can be
based on actual higher capital cost subject to approval)
This has impact on
Interest on debt
Return on Equity Incentive payment
Depreciation
O & M expenses
Insurance expenses
Foreign exchange variation in interest, debt repayment and ROE
Bid route cases No such risk as a fixed amount is paid per unit of energy generated,
no matter what was the actual cost of completion of the project.
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Comparison of price risk to utility in the two methods of
calculating fixed cost
MoU cases-other issues
Increased burden on utility to constantly verify
the current sources of debt- IPPs keep swapping
high cost debt with low cost debt as a cost
reduction measure.
Utility has to track the interest charged by banks
from time to time on working capital loans
each bank in the consortium may lend atdifferent rates.
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How fixed costs were reduced for GVKby renegotiating
PPA terms
Project cost of Rs.816 crores as per TEC wasfixed as ceiling though actual completed cost was
Rs.1025 crores.
This saving of Rs.209 crores has positive impact
on all the fixed charge components interest,
depreciation, ROE, O & M and insurance
charges.
The levelized tariff with Rs.1025 cr. of projectcost is Rs.2.6904 per Kwh vis--vis Rs. 2.6275
per Kwh with Rs.816 cr. of project cost.
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How fixed costs were reduced for GVKby renegotiating
PPA terms
Reduction in O & M charges from 2.5% to 2% -this reduces the payment to IPP by Rs.40.8 cr
p.a.
The effect on levelized tariff is a reduction by
2.54 paise per kwh.
The term of PPA was reduced from 30 years to
18 years by an amendment to PPA.
Amendment provided for a rebate of 2.5% to beallowed to the utility if it settles a bill within 5
days reduces levelized tariff by 0.27 paise.
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Actual Fixed Costs for 2001-02
Name of IPP Fixed cost
In Rs. Per kwh
GVK 1.52
Spectrum 1.61
Kondapalli 1.22
Balaji 1.52
Tannirbavi 1.98
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Incentive payment
Basis of payment
GVK
For every 1% increase in PLF from 68.5% to 85%, .0525% of
additional ROE.
Incentive payable on notional generation also.
PPA was amended to reduce rate of incentive from .6% to
.525% and also to cap incentive payment at 85% PLF.
Effect is to reduce maximum ROE payment including
incentives to 25% from 35%. Applied to equity of
Rs.243.23 crores, this amounts to a saving of Rs.24.32 cr
p.a.
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Incentives
Spectrum Power
Basis of payment
68.5% to 80.5% .4% for every 1% increase in PLF
80.5% to 85.5% .5% for every 1% increase in PLF
above 68.5%
> 85.5% .6% for every 1% increase in PLF
above 68.5%
Kondapalli Power
80% to 85% PLF 2% of Other Fixed Charges (OFC)
85% to 90% PLF 10% + 3% for every 1% increase inROE above 85%
> 90% Same as for 90% i.e 25% of OFC
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Comparison ofIncentives
GVK Spectrum Kondapalli
Maximumpossible ROE
including
incentives
25% 34.9% 26.7%
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Scope for further reduction in fixed cost
Floor for incentives should be at around 80% and
not at 68.5%
No incentive on deemed/notional generation
Term loans which are in strong currencies likeEuro should be swapped.
Repayment of debt should be reimbursed rather
than depreciation.
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Repayment of debt instead of depreciation
PPAs of MoU projects provide for recovery of
capital by way of reimbursement of depreciation
Entire project cost (including land cost in some
cases) is taken as comprising of depreciable fixedassets
Assets are depreciated on straight line basis over a
12 year period up to 90% of original value.
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Why not depreciation?
Depreciation is recovery of capital
Reimbursing depreciation as part of fixed charges
amounts to recovery of not only debt but also
equity Power price is meant to include only return on
equity and not return of equity,
Major portion of equity is also returned to investor
in the process.
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Conclusion
It is possible to bring down cost of power generated evenby existing IPPs.
IPP not a bad word!
Negotiate-benchmark against the most competitive bid
received. Utility should set payment track record to generate
confidence among IPPs, rather than setting up payment
security mechanisms.
Set up infrastructure on priority basis to distribute gas andconvert liquid fuel based projects to gas.
Key role for regulator and utility in the entire process.
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