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Presentation Title ( Arial, Font size 28 )
Date, Venue, etc..( Arial, Font size 18 )
Tata Power Trading Company Ltd
Power Procurement: Planning, Regulations and Practices
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AGENDA
Introduction of Tata Power & Tata Power Trading Company Limited
Power Market Structure and Developments
Power Procurement Planning
Power Procurement Regulations
Power Procurement Practices
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TATA POWER COMPANY – BUSINESS OVERVIEW
Established in 1910, Tata Power is India's largest integrated power company with a
significant international presence
The Company has gross power generation capacity of 8914 MW out of which 7675 MW
from Thermal.
Tata Power has an installed generation capacity of 1239 MW through green resources
One of the largest renewable energy players in India
It has developed India’s first 4000 MW Ultra Mega Power Project
Tata Power – International Presence
South Africa - 50: 50 JV with Exxaro Resources (234 MW Wind Project)
Georgia - Development of three hydro projects in 2 phases of 185 MW and 215 MW
Indonesia – Coal Assets and Geothermal project being developed
Zambia - 120 MW Itezhi Tezhi hydro Power Project (2*60 MW)
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TATA POWER TRADING COMPANY LIMITED (TPTCL) - OVERVIEW
A wholly owned subsidiary of The Tata Power Company Limited
First company to be awarded a power trading license by CERC - On 9th June 2004
Cross Border Trading Experience – Importing power from Dagachhu Hydro
Power(126MW), in Bhutan, to India
TPTCL is the UI Pool Member of Eastern region for import from DHPC Bhutan
TPTCL serves DISCOMs across all the states in India
Consistently among the top three power trader in India.
Has increased its trading volume from 2996 MU in FY 2009 to 10500 MU in FY 2015
Revenue of Rs. 4182 Crore(s) i.e. US$642 Million in FY 2015
24 X 7 State of art highly automated control room manned by highly skilled
professionals
Timely payment and payment security to power suppliers
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TATA POWER TRADING COMPANY LIMITED (TPTCL) – SERVICE PORTFOLIO
TPTCL SERVICE PORTFOLIO
Bilateral Power Contracts
Short Term Contracts
Medium/Long Term
Contracts
Power Exchanges
Renewable Energy
Certificate (REC)
Advisory Services
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DEVELOPMENT OF INDIAN ELECTRICITY MARKET STRUCTURE
• Basic Framework of Electricity Market
• License for supply of electricity by State Indian Electricity Act 1910
• Creation of SEBs. Electricity (Supply) Act 1948
• Private Generating Companies to Set up plant & sell power to Grid
Amendment in 1991
• Introduction of Mega Power Project Policy
• To Promote, monitor, purchase power & sell to identified SEBs through a Govt. Company
Amendment in 1995
• Setting up of Independent CERC & SERC.
• Main function to regulate tariff & promote competition, efficiency & Economy
Electricity Regulatory Commission Act 1998
• Participation of Private sector in area of Transmission construction, operation & maintenance under control of CTU & STU.
Amendment in Act-1998
• Generation De-licensed
• Determination of tariff by bidding process Electricity Act 2003
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SALIENT FEATURES OF INDIAN ELECTRICITY ACT 2003
De-licensing of generation
Development of a Multi-Buyer Multi-Seller framework in power
Introduced Tariff based Competitive Bidding for procurement of Power
Provision of Non-discriminatory Open Access
Setting up State Electricity Regulatory Commission (SERC) made mandatory
Development of National Electricity Policy (NEP-2005) and National Tariff Policy (NTP-2016)
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INSTALLED GENERATION CAPACITY
All figs in MW, Source: www.cea.nic.in
Source: Central Electricity Authority
As on 30.09.2015
Thermal Nuclear Hydro RES Grand Total
Coal Gas Diesel Total Central 49380 7520 0 56900 5780 11491 0 74171 State 59451 6974 439 66863 0 27672 1919 96455
Private 60287 9594 555 70436 0 3120 34551 108108 Total 169118 24088 994 194200 5780 42283 36471 278734
Thermal 70%
Nuclear 2%
Hydro 15%
RES 13%
Generation Mix
Central 27%
State 34%
Private 39%
Sector-Wise Generation
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POWER SUPPLY POSITION IN INDIA
Source: CEA
The power supply position in the country during 2010-11 to 2014-15 :
Energy Peak
Year
Requirement Availability Surplus/Deficts(-) Peak
Demand Peak Met Surplus/Deficts(-)
(MU) (MU) (MU) (%) (MW) (MW) (MW) (%)
2010-11 861,591 788,355 -73,236 -8.5 122,287 110,256 -12,031 -9.8
2011-12 937,199 857,886 -79,313 -8.5 130,006 116,191 -13,815 -10.6
2012-13 998,114 911,209 -86,905 -8.7 135,453 123,294 -12,159 -9
2013-14 1,002,045 959,614 -42,431 -4.2 135,918 129,815 -6,103 -4.5
2014-15 1,067,085 1,028,955 -38,130 -3.6 148,166 141,160 -7,006 -4.7
0
2
4
6
8
10
12
0
2,000
4,000
6,000
8,000
10,000
12,000
14,000
16,000
2010-11 2011-12 2012-13 2013-14 2014-15
Deficit in Peak - (MW)/(%)
Deficit (MW) Deficit (%)
0
2
4
6
8
10
12
0
20,000
40,000
60,000
80,000
100,000
2010-11 2011-12 2012-13 2013-14 2014-15
Deficit Energy - (MU)/(%)
Deficit (MU) Deficit (%)
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STRUCTURE OF INDIAN POWER MARKET
Regulations
System Operators
Generation
Concurrent Policy Making Central Government 29 State Governments
Central Electricity Regulatory Commission
State Electricity Regulatory Commissions
National Load Dispatch Center
State Load Dispatch Centers
Central Generating Stations
IPPs
Transmission
State Generating Stations
Central Transmission Utility
IPTC State Transmission
Utilities
Regional Load Dispatch Centers
Distribution Private Distribution Companies*
Markets
State Distribution Companies
Power Exchanges Bilateral Markets
* Private distribution companies are few in number. Tata Power-Mumbai and Tata Power- Delhi are amongst the best performing distribution companies
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INDIAN POWER MARKET STRUCTURE – TYPES OF CONTRACTS
Nature of Contract Duration of Contract Transmission Open access
availability
Long Term 20 years or more Long term open access is available for a period of 12 years to 25 years
Medium Term >1 years to 5 years Medium term open access is available for a period of 4 months to 3 years
Short Term
Short Term – Bilateral Up to 1 year For a period of up to 3 months
Short Term – Power Exchange Day Ahead Market (1 day)
1 day (corridor left after short term bilateral)
Term Ahead Market ( Week Ahead)
Weekly basis (FCFS/Day Ahead)
Deviation Settlement Mechanism
Real time balancing mechanism for settling deviation from schedule
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NEED FOR PLANNING
Inefficient power procurement planning adversely impacts the finances of the Discoms in
several ways:
Indirect consequences of shortage of power are the following:
Due to operational constraints paying consumers confront load shedding.
In a shortage situation, incremental loss of generation may lead to load shedding to HT
Categories in order to ensure minimum supply to domestic/agricultural categories:
Higher distribution losses due to reduced sales to HT categories.
Migration of customers from subsidizing categories (HT industrial/commercial) to other
sources of power procurement under Open Access or Captive routes.
Ideally shortage of power leads to higher power purchase cost due to the following
reasons:
Higher proportion of short term power purchases
Higher fuel cost due to usage of expensive fuels by long term generation sources
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ISSUES FACED BY DISCOMS IN PLANNING
In the past, Discoms failed to procure power as per the plan due to reasons such as:
Fuel shortages (Gas and Coal)
Transmission congestion at different levels:
Inter regional (e.g. WR to NR, ER to NR, Rest of India to SR)
Intra regional (e.g. N3 Import, S2 Import from S1) and
Intra state (e.g. Gurgaon Import in Haryana, NPCL Import in UP, etc.)
Delay in commissioning of power projects
Lower level of hydro generation
Discoms do not conduct sensitivity analysis or probabilistic analysis and ascertain more
realistic power procurement requirements in the future.
Competitive bidding for power procurement is not conducted in a timely manner.
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TRANSMISSION CORRIDOR PRIORITY
Long
Term Medium Term
Short Term
(Advanced Reservation /First Come First Serve)
Short Term PX(DAM)
Short Term Day
Ahead/Contingency/Same
day
Discoms must keep in mind the priority for transmission corridor related
to various options available for power procurement.
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POWER PROCUREMENT ROUTES
Power Procurement
MoU route
PPA Banking
Competitive route
Competitive bidding
guidelines (DBFOO and
DBFOT)
Markets – OTC & PXs
DBFOO- Design Build Finance Own and Operate
DBFOT- Design Build Finance Operate Transfer
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POWER PROCUREMENT- CONSUMERS
Reliability of supply and competitive rates are the two primary reasons why consumers
use the open access route to procure electricity.
The Electricity Act 2003 has created this option for sourcing of power to create a market
driven regime opposed to supply of electricity through state monopolies.
The Act provides that industries in need of more than 1 MW electricity can procure power
from electricity exchanges or directly from generators and distribution companies or traders
of power.
Many state governments and utilities have stopped giving out permissions for open
access by imposing restrictions on movement of power from sellers to users.
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INDIAN POWER MARKET – PERCENTAGE ENERGY SHARE
Largely tied-up through Long term PPAs
Short term bilateral market dominated
by few players accounting for over 85%
volume of short term market
Low liquidity in short term market
Coal India Limited (CIL) giving coal only
for long term PPAs
Unscheduled Interchange (UI) volume is
progressively declining because of
tightening of frequency band by Central
Electricity Regulatory Commission) CERC
and emergence of Power Exchange (PX)
91%
4%
3% 2%
Percentage Energy Share - Contract Wise
Long Term Short Term-OTC
Short term - PX Short Term-UI
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POWER PROCUREMENT OPTIONS AVAILAIBLE FOR A DISCOM
Procurement of Power Exchanges/Traders Procurer can select a capacity from
multiple resources for varying capacities and for varying contracts.
Base Load
• Coal
• Nuclear
Peak Load
• Hydro
• Gas
Renewable
• Solar
• Wind
• Others
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SCHEMATIC APPROACH TO POWER PROCUREMENT
Procurers of complex portfolios would ideally need to update the contracting strategy
for procurement of power on an annual basis
Market conditions in terms of demand-supply gap, electricity prices and regulatory
conditions would determine the risks and costs
The risks and costs would determine the selection of the combination of contracts
Short term/Medium term/Long term
Bilateral/Power Exchanges
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LONG TERM / MEDIUM TERM POWER PROCUREMENT
Demand Projection
As per 18th Electric Power Survey (EPS) by CEA
CAGR
Estimated availability from Long Term Supply
Latest Information Available from Various Sources like CEA, Meetings, Seminars, Site Visits etc.
Demand Supply Gap Estimated
Planning for Shortfall / Surplus Arrangements
Types of Arrangements
Allocated
Contracted (Competitive Bidding)
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SHORT TERM POWER PROCUREMENT
Estimated Demand Projection –One year Ahead (Reviewed Monthly or Earlier –As required –Max./ Avg. Probability)
Scenario Building on Parameters such as weather, festivals, public elections etc.,.
Estimated supply from Long Term Supply based on Load Generation Balance Report (LGBR), planned plant outages, contingency , fuel availability etc.,.
Estimated Demand Supply Gap.
Planning for Shortfall / Surplus Arrangements
Types of Arrangements
Bilateral
Banking
Power Exchanges
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DECISION MATRIX FOR SHORT TERM SALE / PURCHASE
Banking
Tender/Bilateral
Banking / Purchase Banking / Sale
Surplus / Shortage
START
Identification of Shortage / Surplus
(Monthly/Fortnightly/Hourly)
Sale Tender/Bilateral/
PXs
Banking
Tender/Bilateral
Purchase Tender/Bilateral/
PXs
Surplus Shortage
Banking Sale Banking Purchase
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SCHEMATIC APPROACH TO POWER PROCUREMENT OPTIMIZATION
Due to the combination of long term, medium and short term supplies, differing fuels, base and peaking contracts and power procurements, optimization has to be done for (a) long term planning and (b) short term procurement and sale
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REGULATORY PROVISIONS
Section 62 of the Electricity Act 2003 states that
“The Appropriate Commission shall determine the tariff in accordance with provisions of this Act for –
(a) supply of electricity by a generating company to a distribution licensee:
Provided that the Appropriate Commission may, in case of shortage of supply of electricity, fix the minimum and maximum ceiling of tariff for sale or purchase of electricity in pursuance of an agreement, entered into between a generating company and a licensee or between licensees, for a period not exceeding one year to ensure reasonable prices of electricity;”
Section 63. (Determination of tariff by bidding process):
“Notwithstanding anything contained in section 62, the Appropriate Commission shall adopt the tariff if such tariff has been determined through transparent process of bidding in accordance with the guidelines issued by the Central Government”
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POWER PROCUREMENT REGULATIONS
The Electricity Act 2003 Dated 2nd June 2003
National Electricity Policy Dated 12th February 2005
National Tariff policy 28th January 2016
Guidelines for short term procurement of power by distribution licensees through tariff based bidding process dated 15th May 2012
Guidelines for procurement of Electricity from Thermal Power Stations set up on Design, Build, Finance, Operate and Transfer (DBFOT) basis dated 21st September, 2013
Guidelines for procurement of Electricity from Thermal Power Stations set up on Design, Build, Finance, Own and Operate (DBFOO) basis Dated 9th November, 2013
Guidelines for procurement of electricity for medium term from power stations set up on Finance, Own & Operate (FOO) basis dated 10th February 2014 and amendment dated 20th August 2015.
Guidelines for procurement of peaking power for medium term dated 24th February 2014
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MOP GUIDELINES FOR PROCUREMENT OF SHORT TERM POWER
Guidelines dated 15th May 2012 shall be used for short term procurement of power by
distribution licensees through tariff based bidding process
Exception: i) Power procured for less than 15 days
ii) Banking Mechanism
iii) Power exchanges
Single Tariff at delivery point up to three decimal places. (No escalation)
Option of Supply from alternate source.
Single stage process
RFP to be published in at least two National Newspaper.
RFP to include: i) Requirements (Quantum, timeslot, duration)
ii) Delivery point
iii) Procedure and Criteria to be used to evaluate bids to be given
iv) Earnest Money Deposit (EMD), Bank Guarantee,
v) Contract Performance Guarantee
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MOP GUIDELINES FOR PROCUREMENT OF SHORT TERM POWER
Validity of Bid for 10 days.
Draft PPA to be part of RFP
Important provisions for PPA i.e. Force Majeure Events, Billing Cycle, Compensation
clause, Payment terms and Payment security mechanism.
Requirement of at least two bidders.
Procurer to constitute a standing committee for evaluation of bid with one external
member.
No deviations from this guidelines allowed except with prior approval of regulatory
commission.
Provides for dispute settlement through arbitration under the Indian arbitration and
Conciliation act 1996
Timeline for Process: RFP issued – Zero Date
Submission of RFP Bid – 6 Days
Evaluation of bids and signing of PPA – 10 Days
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ISSUES IN MOP GUIDELINES FOR SHORT TERM
Absence of “Late Payment Surcharge” clause leading to payment risk for traders
Implementation issues at state level
EMD amount of Rs.30,000/MW/Month is quite high for a period of procurement less than one month
LC equivalent to 100% of the weekly energy corresponding to contracted capacity at the tariff is less and same should be equivalent to the billing cycle of the contract.
Absence of “Right to Regulate” clause
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ISSUES IN SHORT TERM POWER PROCUREMENT
Poor Financial Health of Discoms
Transmission Constraints
Fuel price risk
Shortfall in coal supply
Lack of regulatory clarity for import of power
Implementation of Open Access at state level
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REVERSE AUCTION (1/3)
Recently WBSEDCL has procured power through Reverse Auction for the period
January 2016 to June 2016 in two phases
WBSEDCL carried out power procurement through two phase bidding
Competitive bidding through tender
Reverse Auction (L1 price of competitive bidding is the start bid price)
The bidders have to submit Quantum and Price in e-portal.
Minimum quantum required for participation were 150/50 MW
Minimum price tick was 1 paisa/kWh
Reverse Auction started at 11 AM and continued up to 12:30 midnight/6:30 PM
At the same price, quantum was given priority
Auto extension time were 10 minutes and 5 minutes
Prices discovered through Reverse Auction was substantially low compared to standard
competitive bidding through Tender.
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REVERSE AUCTION (2/3)
Subsequently, Ministry of Power (MOP) has decided to use Reverse Auction
mechanism for procurement of power
Expected Advantages of Reverse Auction are as follows:
Each procurers will have the complete knowledge of nation wide power
procurement
Standardization of process to help in streamlining procurement and reduce
procurement time and costs.
The bidding will be electronic, thus eliminating need for bidder interaction before
finalization of contract
Reverse Auction being real-time tool for price discovery, excepted to ensure best
price for DISCOMs.
MSTC has been identified as service provider for providing e-platform
MSTC has presented a demo to stake holders at PFC office on 1st February 2016
Initially Reverse Auction will be used for Short Term power procurement
Medium Term and Long Term procurements through Reverse Auction at a later stage
MOP is in the process of revising the guidelines for procurement of short term power
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REVERSE AUCTION (3/3)
Salient features of proposed reverse auction
Two stage process
Single quantum and price to be quoted by the bidder irrespective of generation
sources
Minimum quantum to be decided by respective procurer
Price tick to be one paisa per kWh
Gate closure after two hours
No time extension
Prices discovered through Reverse Auction in WBSEDCL Tenders:
Sl. No.
Month Quantum Rate
1 Jan-16 500 MW 2.86
2 Feb-16 500 MW 2.91
3 Mar-16 500 MW 2.75
4 Apr-16 500 MW 2.82
5 May-16 500 WM 2.90
6 Jun-16 500 MW 2.81
Sl. No.
Month Quantum Rate
1 8th to 15th Mar-16 150 MW 2.61
4 16th to 31st Mar-16 500 MW 2.61
5 Apr-16 500 WM 2.76
6 May-16 300 MW 2.70
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ANCILLARY SERVICES MARKET
Central Electricity Regulation Commission (CERC) published its notification dated 13th
August 2015 called the Central Electricity Regulatory commission (Ancillary Services
Operations) Regulations, 2015
Objective of these regulations is to restore the frequency at desired level and to relieve
the congestion in the transmission network
It is applicable to the Regional Entities involved in the transactions facilitated through
open access in inter-State transmission of electricity
RRAS (Reserves Regulation Ancillary Services) shall be provided by regional entities
whose tariff is determined or adopted by the Commission for their full capacity
National Load Despatch Centre (Nodal Agency) through the Regional Load Despatch
Centres shall be responsible for implementation of the ancillary services through merit
order stack.
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MOP GUIDELINES FOR PROCUREMENT OF MEDIUM TERM & LONG TERM POWER
Ministry of Power first issued guidelines for competitive bidding process, to be followed by DISCOMs for long/medium term power procurement, on 19th January 2005.
Power Procurement on Long Term basis - Fresh guidelines were issued on 21st September 2013 for Case-2 bidding process , on 9th Nov 2013 for Case-1 bidding process
Power Procurement on Medium Term basis - Fresh guidelines were issued on 10th February 2014 and 24th February 2014 and amendment dated 20th August 2015
The guidelines have been framed under the provisions of Section 63 of the Act.
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LONG TERM - CERC TARIFF FRAMEWORK
• Tariff for supply of electricity from a thermal generating station shall comprise two
parts:
i. capacity charge (for recovery of annual fixed cost)
ii. energy charge (for recovery of primary and secondary fuel cost )
• The tariff for supply of electricity from a hydro generating station shall comprise
capacity charge and energy charge for recovery of annual fixed cost through the two
charges
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• Capacity Charges shall be derived on the basis of Annual Fixed Cost and shall
consist of the following components:
i. Return on equity
ii. Interest on loan capital
iii. Depreciation
iv. Interest on working capital
v. Operation and maintenance expenses
• Energy charges shall be derived on the basis of the landed fuel cost (LFC) of a
generating station (excluding hydro) and shall consist of the following :
i. Landed Fuel Cost of primary fuel
ii. Cost of secondary fuel oil consumption
CERC TARIFF FRAMEWORK
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LONG TERM POWER PROCUREMENT - OPTIONS
Long Term Power
Procurement
DBFOO
(Case-1)
Location & Fuel not specified
DBFOT
(Case -2)
Location & Fuel are specified
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KEY FEATURES FOR PROCUREMENT OF POWER FROM THERMAL POWER STATIONS SET UP ON DBFOT BASIS MOP published the guidelines on 21st September 2013 for procurement of electricity
from thermal power stations set up on Design, Build, Finance, Operate and Transfer
(DBFOT) basis
Two stage competitive bidding process:
Request for Qualification (RFQ) stage
Request for Proposal (RFP) stage
Term of contract shall be 20 years or more
Utility shall pay a fixed charge determined through competitive bidding for
availability of the power station and shall be revised annually to reflect 30% of the
variation(annual change) in WPI and CPI. Further annual reduction of 2% so that the
benefit of a depreciated asset is passed on to the consumers.
Fuel charge is pass through subject to certain ceiling
Normative availability shall be 90% of the Installed Capacity
Tariff to be quoted for first year only (no levelized tariff)
At the end of concession period, the power plant will be transferred to the utility
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KEY FEATURES FOR PROCUREMENT OF POWER FROM THERMAL STATIONS UNDER DBFOO BASIS
MOP published the guidelines on 9th November 2013 for procurement of electricity from thermal power stations set up on Design, Build, Finance, Own
and Operate (DBFOO) basis Two stage competitive bidding process:
Request for Qualification (RFQ) stage
Request for Proposal (RFP) stage Term of contract is for 25 years and extendable by 5 years Utility shall pay a fixed charge determined through competitive bidding for
availability of the power station and shall be revised annually to reflect 30% of the variation in WPI. Further annual reduction of 2% so that the benefit of a depreciated asset is passed on to the consumers.
Fuel charge is pass through subject to certain ceiling Normative availability shall be 90% of the contracted capacity Tariff to be quoted for first year only (no levelized tariff)
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KEY FEATURES FOR PROCUREMENT OF ELECTRICITY FOR MEDIUM TERM FROM POWER STATIONS SET UP ON FOO BASIS MOP published the guidelines on 10th February 2014 for procurement of
electricity from power stations set up on Finance, Own and Operate (FOO)
basis and amendment dated 20th August 2015 Two stage competitive bidding process:
Request for Qualification (RFQ) stage
Request for Proposal (RFP) stage Term of contract shall be one to five years, with a provision for extension of
this period for the lower of 25% of the initial contract period and one year,
with mutual consent Utility shall pay a fixed charge determined through competitive bidding for
availability of the power station and shall be revised annually to reflect 20% of
the variation in WPI. Fuel charge is pass through Normative availability shall be 85% of the contracted capacity
Traders are allowed to participate in bidding process
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COMPETITIVE WHOLESALE MARKET
Captives
Power Exchanges
Merchant Power Plant
Regulated Generators
Traders
Distribution Companies
Consumer Consumer Consumer
“Arrow” represents “Contracts possible for Sale/Purchase of Power”,
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SHORT TERM POWER MARKET TRENDS
47
Source: CERC Market Monitoring Report
8.50%
9.00%
9.50%
10.00%
10.50%
11.00%
11.50%
0
10000
20000
30000
40000
50000
60000
FY11 FY12 FY13 FY14 FY15
MU
s
Financial Year
Short term Market Trend
Bilateral
PX
UI
% of total generation
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SHORT TERM POWER MARKET TRENDS
48 Source: CERC Market Monitoring Report
65.9 81.56 94.51 98.94 104.64 98.99
9.00%
10.00%
11.00% 11.00% 10.87%
9.47%
0.00%
2.00%
4.00%
6.00%
8.00%
10.00%
12.00%
0
200
400
600
800
1000
1200
2009-10 2010-11 2011-12 2012-13 2013-14 2014-15
BU
Short -term Transactions of Electricity
Total Generation (BU)
Short-term Transactions of Electricity (BU)
Total volume of Short-term Transactions of Electricity as % of Total Electricity
Generation
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SHORT TERM POWER MARKET TRENDS
49 Source: CERC Market Monitoring Report
21.92
26.72 27.7
35.84 36.12 35.11 35.49
2.77
7.19
15.52 15.54
23.54
30.67 28.46
24.69
33.91
43.22
51.38
59.66
65.78 63.95
0
10
20
30
40
50
60
70
2008-09 2009-10 2010-11 2011-12 2012-13 2013-14 2014-15
Volume of Electricity Transacted through Trading Licensees and Power
Exchanges
Electricity Transacted Through Traders + TAM (BU)
Electricity Transacted through PX (BU)
Total BU
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SHORT TERM POWER MARKET TRENDS
50
Source: CERC Market Monitoring Report
0%
5%
10%
15%
20%
25%
30%
35%
40%
45%
0
20
40
60
80
100
120
2008-09 2009-10 2010-11 2011-12 2012-13 2013-14 2014-15
Volume of Electricity transacted through UI
Volume of UI (BU)
Total Volume of Short term (BU)
Volume of UI as % of ST Volume
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SHORT TERM POWER MARKET TRENDS
51 Source: CERC Market Monitoring Report
7.29
5.26
4.79
4.18 4.33 4.29 4.28
7.49
4.96
3.47 3.57 3.67
2.9
3.29
0
1
2
3
4
5
6
7
8
2008-09 2009-10 2010-11 2011-12 2012-13 2013-14 2014-15
Rs.
/kW
h
Price of Electricity Transacted through Traders & Power Exchanges
Price of Electricity transacted through Traders (All India Average Inc. SR)
Price of Electricity transacted through Power Exchanges (MCP - Unconstraint)
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AP FINANCIAL BID (2400/3400 MW) OPENED ON 25.06.2015
Sl. No. Developer Plant Location Offered
Quantum (MW)
Cumulative Quantum
(MW)
Fixed Charge (Rs/kWh)
Fuel Charge (Rs/kWh)
Total Tariff (Rs/kWh)
1 East Coast Srikakulam, AP 488.55 488.55 2.86 1.41 4.27
2 NCC Nellore, AP 500 988.55 2.56 1.79 4.35
3 Korba West Raigarh, Cg 540 1528.55 3.5 0.99 4.49
4 MB Power Ltd. Annuppur, MP 374.15 1902.70 3.63 1.06 4.69
5 Jindal India Thermal Power Ltd.
Angul, OR 400 2302.70 3.79 1.04 4.83
6 Essar Power Singrauli, MP 500 2802.70 3.80 1.03 4.83
7 Lanco Power - Amarkantak Korba, CG 1181 3983.70 4.09 0.89 4.98
8 Indiabulls Nasik, MH 1242 5225.70 3.36 1.89 5.25
9 R.K.M Powergen Champa, CG 300 5525.70 3.52 1.87 5.39
10 KVK Nilachal Power Pvt. Ltd. Cuttak, OR 250 5775.70 4.40 1.20 5.60
11 D B power Champa, CG 303 6078.70 4.31 1.41 5.72
12 Ind Bharat (Madras) Limited Tuticorin, TN 500 6578.70 3.15 3.16 6.31
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UPPCL 2800 MW RFQ PARTICIPANTS LIST DATED 18.08.2015
Sl. No. Developer Plant Location Offered Quantum
(MW) Cumulative
Quantum (MW)
1 Dhariwal Infrastructure Limited Chandrapur, MH 300 300
2 MB Power MP Limited Anuppur, MP 374.15 674.15
3 Lanco Amarkantak Korba, CG 1254 1928.15
4 JITPL Angul, OR 411 2339.15
5 Rattan India Power Nashik, MH 1350 3689.15
6 NCC Power Nellore, AP 200 3889.15
7 Vandana Vidyut Korba, CG 200 4089.15
8 RKM Powergen Janjgir-Champa, CG 350 4439.15
9 SKS Power Raigarh, CG 270 4709.15
10 BALCO Korba, CG 200 4909.15
11 Jindal Power Limited Raigarh, CG 325 5234.15
12 Monnet Power Angul, OR 300 5534.15
13 Adani Power Mundra, Gujarat 370 5904.15
14 India Power Corporation Ltd Haldia, WB 300 6204.15
15 Athena Power Janjgir-Champa, CG 450 6654.15
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TPDDL LONG TERM POWER PURCHASE TENDER RESULTS (400 MW)
SL. No. Bidder Quantum in
MW Total tariff in
Rs./kWh Fixed Cost in
Rs./kWh Variable Cost in
Rs./kWh
1 JITPL 200 3.99 3.226 0.764
2 BALCO 120 4.071 3.077 0.994
3 MB Power 374.15 4.23 3.251 0.979
4 LANCO Anpara 100 4.24 3.07 1.17
5 Rattan India 400 4.479 2.497 1.982
6 GMR 400 4.48 3.27 1.21
7 SKS 240 4.5 3.519 0.981
8 Adani 250 4.529 3.022 1.507
9 ESSAR 400 4.608 3.734 0.874
10 JP Nigrie 200 4.77 4.163 0.607
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RECML MT POWER PROCUREMENT RESULTS
2.66
2.88 2.94
3.00
3.32
3.60 3.69
2.90 2.88 2.94
3.06
3.60
2.80
2.96 3.00
3.18
2.98
3.18 3.20
2.30
2.50
2.70
2.90
3.10
3.30
3.50
3.70
3.90
L1 L2 L3 L4 L5 L6 L7
Pri
ce (R
s/U
nit
)
Quoted Ex Bus Power Prices
RECML MT Power Procurement Results
ER NR WR
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