Power Procurement: Planning, Regulations and … Training-2016/IITK - PPTs - 2016/Day... · Power...

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Tata Power Trading Company Ltd

Power Procurement: Planning, Regulations and Practices


AGENDA

Introduction of Tata Power & Tata Power Trading Company Limited

Power Market Structure and Developments

Power Procurement Planning

Power Procurement Regulations

Power Procurement Practices



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)


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


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



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)


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


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 (%)


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


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



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


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.


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.


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


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.


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


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


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


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)


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


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


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



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”


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


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


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


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


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


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.



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



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


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.


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.


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


• 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


LONG TERM POWER PROCUREMENT - OPTIONS

Long Term Power

Procurement

DBFOO

(Case-1)

Location & Fuel not specified

DBFOT

(Case -2)

Location & Fuel are specified


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


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 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)


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 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


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”,



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



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




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



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




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)


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


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


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


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


Date post:	23-Jul-2018
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