Electricity Trading on Power Exchange (Dissertation Report)
COMMERCIAL
Knowledge Management System
Electricity Trading on Power Exchange
Key Words : Financial Market, Retail Market, Deregulation, Load Management
Submitted by : Shri R.R.Bolisetty, Sr.Manager(OS), WRHQ, 9869223061,
10/1/2007
Electricity Trading on Power Exchange
A Dissertation Proposal for
XVII National Management Programme
by
Ramachandra Rao Bolisetty
under the guidance of
Shri DK Gupta Dr. A Sahay DGM, Chairman, NMP NVVN, NTPC MDI, Gurgaon
Management Development Institute
Gurgaon 122 001
October 25, 2005
Electricity Trading on Power Exchange
A dissertation submitted in partial fulfillment of the requirements for the award of
Post-Graduate Diploma in Business Management
by
Ramachandra Rao Bolisetty
XVII National Management Programme
Management Development Institute
Gurgaon 122 001
October, 2005
Electricity Trading on Power Exchange
A dissertation submitted in partial fulfillment of the requirements for the award of
Post-Graduate Diploma in Business Management
by
Ramachandra Rao Bolisetty
under the guidance of
Shri DK Gupta Dr. A Sahay DGM, Chairman, NMP NVVN, NTPC MDI, Gurgaon
XVII National Management Programme
Management Development Institute
Gurgaon 122 001
October, 2005
Certificate of Approval
The following dissertation titled "Electricity Trading on Power Exchange" is hereby approved as a certified study in management carried out and presented in a manner satisfactory to warrant its acceptance as a prerequisite for the award of Post- Graduate Diploma in Business Management for which it has been submitted. It is understood that by this approval the undersigned do not necessarily endorse or approve any statement made, opinion expressed or conclusion drawn therein but approve the dissertation only for the purpose it is submitted. Dissertation Examination Committee for evaluation of dissertation
Name Signature 1. External Examiner _______________________ ___________________
2. Internal Examiner _______________________ ___________________ 3. NMP Dissertation Coordinator _______________________ ___________________
Certificate from Dissertation Advisory Committee This is to certify that Mr. Ramachandra Rao Bolisetty, a participant of the XVII National Management Programme, has worked under our guidance and supervision. He is submitting this dissertation titled Electricity Trading on Power Exchange in partial fulfillment of the requirements for the award of the Post Graduate Diploma in Business Management. This dissertation has the requisite standard and to the best of our knowledge no part of it has been reproduced from any other dissertation, monograph, report or book. (DK Gupta) (Dr. A Sahay) Organisational Advisor Faculty Advisor Deputy General Manager Chairman, NMP NVVN Limited, Management Development Institute, 3rd Floor, Core 5, Gurgaon 122 101 Scope Complex,
Lodhi Road, New Delhi 110 003
Abstract
Electricity Trading on Power Exchange
By
Ramachandra Rao Bolisetty
The Indian electricity industry is marred by inefficiencies. The state electricity boards, which were supposed to cater to the needs of the states, failed miserably in augmenting capacities. The widening of the peak demand shortages and energy shortages compelled the government of India to take appropriate steps towards correcting the scenario. Setting up of central sector generating stations, unbundling of state electricity boards, securitisation of long pending dues, installation of regulators at central as well as at state level and enactment of electricity act 2003 are all the actions initiated in the direction of bringing in accountability and ensuring that power to all by 2012 is realised. With the enactment of Electricity Act 2003, the electricity industry in India is going through reforms and restructuring. It has been observed there are capacities unutilized in one part of the country while there are shortages in the other part of the country. Open access to the transmission network without any discrimination has opened new vistas for trading such surplus energy. The study is focused on possibility of setting up a power exchange and trading of energy over the exchange. The major findings of the study are:
1. At present around 2.5% of total energy generated in India is being traded. The trading is being carried out through traders approved by CERC. The trading is being done at a negotiated price over the open access transmission corridor availability. It is forecasted that around 8% of the total energy generated would be available for trading. Hence, even with the present set of trading arrangements, there is a huge scope for development of the markets.
2. It has been found that there is energy that often is left
unutilized for the want of market mechanism, which could facilitate trading of energy available over short notice without the present day obligations of negotiations.
3. The setting up of power exchange would apart from facilitating the trading of electricity would bring in competition in the short-term electricity markets and realize the realistic price for electricity.
4. The power exchange also would provide signals to the market
for the industry to take wise investment decisions. For carrying out the study, various conceptual models of the power trading and business models were studied. This part of the study is mostly based on the study material and textbooks written in this field of restructuring the electricity industry. Later for developing the market model and Indian perspective various articles, documents of ministry of power, Central Electricity Regulatory Commission and various web sites are extensively studied. The experience of markets around the world has given in sights into the advantages and pit falls in such a market mechanisms. The proposed model is developed in line with the developments envisaged in the Electricity Act 2003 and our National Electricity Policy. The views of experts in the field and their comments, obtained during review are summarized and appropriately incorporated in the model.
Acknowledgements
I am grateful to my guides - Dr. A. Sahay, Chairman NMP, MDI, Gurgaon, who acted as my faculty guide and Shri DK Gupta, DGM, NVVN, NTPC, Delhi, who acted as my internal guide - for their able guidance, constant encouragement, constructive criticism which inspired me to put in greater efforts into this project. I would like to express my deeper gratitude to Prof. Srikrishna A Khaparde, Professor, Electrical Engineering, IIT, Mumbai and Member, Advisory Committee, MERC for his guidance in setting the project on track and constant support and encouragement provided during the entire tenure of this project. I also put it on record, my sincere appreciation to Shri Abhijit R Abhyankar, Ph. D. Scholar, EE, IIT, Mumbai for his constant help in understanding the subject, which immensely helped in writing this dissertation project report. I would like to express my special gratitude to Shri Prabodh Bajpai, Senior Research Fellow, IIT, Kanpur who had provided me with the material to begin with and introduced me to the IIT, Bombay team, without it would have been impossible to complete the project within such short interval. A large number of my colleagues from within the organisation and friends from across the industry have helped by offering their opinions, the articles they have come across, which has helped in broadening my horizon. I also would like to put on record my sincere appreciation for all those involved in the discussions during review of the proposed model. These discussions helped me understand the areas my ignorance. Last but not the least, I would like to place my sincere gratitude to the members of my family - my wife, who have understood my obsession with the studies and unconditionally supported me emotionally by shouldering the responsibility of family front single handedly and children, who at this tender age has shown immense maturity by deferring their needs demanding my time. Mumbai Ramachandra Rao Bolisetty October 25, 2005
Table of Contents
Chapter No.
Description Page No.
1 . Market models in Electricity 1 1.1 Introduction 2 1.2 Historical Background 2 1.2.1 Regulation 3 1.2.2 Deregulation 4 1.2.3 Decentralization 6 1.2.4 Restructuring 10 1.2.5 Open Access 11 1.3 Industry Classification 12 1.3.1 Based on trading 12 a. Integrated model 12 b. Decentralized Model 13 i. Pool Model 14 ii. Wholesale competition 16 iii. Retail competition 17 1.3.2 Based on contractual model 19 a. Bilateral Agreements 20 b. Third Party Agreements 20 c. Power Exchange 20 1.3.3 Based on system operators 24 a. Transmission system operator 25 b. Independent system operator 25 1.3.4 Based on transmission ownership 26 1.3.5 Based on number of participants 27 a. Monopoly 27 b. Oligopoly 28 c. Perfect competition 28
2 . Markets in Transmission and system operation 2.1 Introduction 29 2.2 Transmission Pricing 29 2.2.1 Flat fee 30 2.2.2 Postage stamp method 30 2.2.3 Mile MW method 30 2.2.4 Contract path method 31 2.2.5 Point of Connection tariff 31 2.3 Imbalance management 32 2.4 Congestion Management 33 2.4.1 PAC Management 34 2.4.2 Counter trade 34 2.4.3 Pro-rata reduction 35 2.4.4 Bidding for residual tr.mission capacity 35 2.4.5 Nodal / Zonal pricing 36
2.4.6 ATC with constrained unit commitment 36 2.5 Ancillary services 37 2.6 Grid security 37 2.7 Hedging risks 38 2.7.1. Futures 39 2.7.2. Options 39 2.7.3. Forwards contracts 40 2.7.4. Swap contracts 40 2.7.5. Contract for Differences (CFDs) 40 2.8 Choice of system operator models 41 2.9 Choice of trading models 41 2.10 Choice of contracts 42 2.11 Choice of transmission ownership 43 2.12 Choice of transmission pricing models 43
3 . Electricity markets around the world 3.1 Introduction 45 3.1.1 Legal rationale 45 3.1.2 Economic rationale 45 3.1.3 Technological advances 46 3.1.4 Strategic aims 46 3.2 Developed Electricity Market Models 46 3.3 England and Wales 47 3.3.1 Introduction 47 3.3.2 Phase I of reforms 48 3.3.3 Pool system 48 3.3.4 Regulatory regime 50 3.3.5 Wholesale market 50 3.3.6 Retail market 50 3.3.7 Learning phase 54 3.4 Nordic Countries (Nord Pool) 55 3.4.1 Day Ahead market 59 3.4.2 Balancing market 59 3.4.3 Financial market 59 3.5 United States 60 3.6 California market 61 3.6.1 Day Ahead and Hour Ahead markets 63 3.6.2 Transmission congestion contracts 63 3.6.3 Comments 64 3.6.4 California Crisis 65 3.7 PJM Interconnection 68 3.8 New York Model 70 3.9 Developing Electricity Market Models 75 3.10 China Model 76 3.11 Japan Model 79
4 . Indian electricity industry 4.1 Introduction 82 4.2 History 82 4.3 Need for regulation / Government control 84 4.4 Evolution and present stage 85 4.5 Causes for deregulation 86 4.6 Critical issues in deregulation 87 4.7 Shifts from earlier electricity acts 88 4.8 Brief about Electricity Act 2003 89 4.9 Future directions of the industry 90 4.9.1 Restructuring 90 4.9.2 Capacity addition 91 4.9.3 Capacity utilisation 91 4.9.4 Load management 92 4.9.5 Loss management 92 4.9.6 Intrastate ABT 93
5 . Proposed model for India 5.1 Introduction 94 5.2 Present trading practices 94 5.3 Need for a Power Exchange 95 5.4 Why National Power Exchange? 95 5.5 Dispatching Mechanism 96 5.6 Electricity market 97 5.7 Basic electricity market 97 5.7.1 Day Ahead Market 98 5.7.2 Hour Ahead Market 99 5.8 Capacities on PX 99 5.9 Congestion management 100 5.10 Time line of Power Exchange 100 5.11 Transmission ownership 101 5.12 Transmission Pricing 101 5.13 System Operator 102 5.14 Settlement Mechanism 103 5.15 Financial Instruments 104 5.16 Management and participants of PX 104 5.17 Development of Real Time Market 105 5.17.1 Real time balances market 105 5.17.2 Real time congestion market 106 5.18 Ancillary services 106 5.18.1 Operating reserves 106 5.18.2 Voltage control 107 5.18.3 Primary response 108 5.18.4 Secondary response 108 5.18.5 Peaking power 109 5.18.6 Standby services 109 5.18.7 Load following 109
6 . Review of the Proposed model 6.1 Introduction 110 6.2 Views of Reviewers 110 6.3 Conclusions 114 Future directions of study 116 Points to make 117 Limitations of study 117 References 118 List of Abbreviations used 120 Annexure I: Details of Participation for review of
the model 123
List of tables
Chapter No.
Description Page No.
1 . Market models in Electricity 1.1 Load flattening effect of TOD based pricing . 9
3 . Electricity markets around the world 3.1 Bidding into Nord Pool 58
List of figures Chapter
No. Description Page
No. 1
. Market models in Electricity
1.1 Load flattening effect due to TOD based pricing 10 1.2 Vertically integrated monopoly business model 13 1.3 Decentralized business model 14 1.4 Pool business model 16 1.5 Wholesale competition business model 17 1.6 Retail competition business model 19 1.7 Double sided auction on power exchange 21 1.8 Single sided auction on power exchange 22 1.9 Merit order clearing of power requirement 22 1.10 Scenario under strategic bidding by a generator 23
3 .
Electricity markets around the world
3.1 England and Wales market model 51 3.2 NETA Electricity Market Major contractual
relationships 53
3.3 Structure of Nord Pool market 56 3.4 Price Area Congestion (PAC) management 57 3.5 Bidding into Nord Pool 58 3.6 Structure of California market 62 3.7 Market structure in PJM interconnection 69 3.8 Structure of New York Electricity Market 73 3.9 Current Power Supply System in Japan 80
List of abbreviations used
1. ABT Availability Based Tariff 2. ACE Area Control Error 3. APDP Accelerated Power Development Programme 4. ASCI Administrative Staff College of India 5. ATC Available Transmission Capacity 6. BETTABritish Electricity Trading & Transmission Agreement 7. BSES Bombay Suburban Electric Supply 8. CaISO California Independent System Operator 9. CalPX California Power Exchange 10. CCGT Combined Cycle Gas Turbine 11. CE Capacity Element 12. CEA Central Electricity Authority 13. CEGB Central Electricity Generating Board 14. CERC Central Electricity Regulatory Commission 15. CESC Calcutta Electric Supply Company 16. CFD Contract for Differences 17. CGS Central Generating Stations 18. CPSU Central Public Sector Undertaking 19. CTU Central Transmission Utility 20. DA Day Ahead 21. Discom/Disco Distribution Company 22. DSM Demand Side Management 23. EA 2003 - Electricity Act 2003 24. EPCos Electric Power Companies 25. ER Eastern Region 26. EHV Extra High Voltage 27. ERCOT Electric Reliability council of Texas 28. ESOP Employee Stock Option 29. FACTS Flexible AC Transmission System 30. FERC Federal Electricity Regulatory Commission 31. FY Financial Year 32. GEB Gujarat Electricity Board 33. Genco Generating Company 34. GUVNL Gujarat Urja Vikas Nigam Limited 35. GW Giga Watt 36. HT High Tension 37. Hz Hertz (unit of frequency) 38. IEGC Indian Electricity Grid Code 39. IIT Indian Institute of Technology 40. IOU Investor Owned Utility 41. IPP Independent Power Producer 42. ISO Independent System Operator 43. KV Kilo Volts 44. kWh kilo Watt hour 45. LDC Load Dispatch Centre 46. LMP- Locational Marginal Price 120
47. LOLP Loss of Load Probability 48. LSE Load Serving Entities 49. MCP Market Clearing Price 50. MCV - Market Clearing Volume 51. MISO - Midwest Independent System Operator 52. MOP Ministry of Power 53. MOU Memorandum of Understanding 54. MW Mega Watt 55. MWh Mega Watt hour 56. NETA New Electricity Trading Arrangements 57. NGC National Grid Company 58. NLDC National Load Dipsatch Centre 59. NR Northern Region 60. NTPC National Thermal Power Corporation Limited 61. NVVN NTPC Vidyut Vyapar Nigam Limited 62. NYISO New York Independent System Operator 63. NYPE New York Power Exchange 64. NYPP - New York Power Pool 65. OASIS Open Access Same time Information System 66. OPF Optimal Power Flow 67. PAC Price Area Congestion 68. PJM Pennsylvania-New Jersey-Maryland 69. PLF Plant Load Factor 70. POC Poitn of Connection 71. PPA Power Purchase Agreement 72. PPP Pool Purchase Price 73. PPS Power Producers and Suppliers 74. PSP Pool Sale Price 75. PTC Power Trading Corporation of India Limited 76. PX Power Exchange 77. R&M Renovation and Modernisation 78. REB Regional Electricity Board 79. REC Regional Electric Company 80. RLDC Regional Load Dispatch Centre 81. Rs. - Rupees 82. SC Scheduling Coordinators 83. SCUC Security Constrained Unit Commitment 84. SEB State Electricity Board 85. SERC State Electricity Regulatory Commission 86. SLDC State Load Dispatch Centre 87. SMP System Marginal Price 88. SO System Operator 89. SPC State Power Corporation 90. STU State Transmission Utility 91. T&D Transmission and Distribution 92. TCC Transmission Congestion Contracts 93. TP Transmission Provider 94. TPC Tata Power Company 95. TSC Transmission Service Charges 121
96. TSO Transmission System Operator 97. UI Unscheduled Interchanges 98. UK United Kingdom 99. UPSERCUttar Prdesh State Electricity Regulatory Commission 100. US - United States of America 101. VAR Volt Ampere 102. VOLL Value of Loss of Load 103. WRPC Western Regional Power Committee
Electricity Trading on Power Exchange
Chapter 1: Market models in electricity
1.1 Introduction
The electricity industry is technically complex and
institutionally complicated. For about more than 100 years, the
industry remained vertically integrated. During that time,
engineers treated the management of this industry as a set of
optimisation challenges [13]. Making competition work in this
complex industry is to be carefully modeled. Regulation is
considered a poor substitute for a competitive market and is
only adopted where, for reasons of natural monopoly or public
interest, competition is not feasible or performs poorly without
government controls. The decade old world experience of
competition in electricity is good and not so good. However,
none of the countries have gone back on introducing
competition. This shows that competition in this industry is
feasible. Competition is what benefits consumers and benefiting
consumers should be what public policy is all about [1].
Whatever may be the market model adopted, it should be able to
deliver the consumers
Lower prices Reliable services Predictable bills and Value added services
1.2. Historical Background
In the last century, when the electrical technology was in the
infancy, government was hesitant to invest huge public capital
in unproven technology. Private investors like Westinghouse,
Edison etc., being confident of the technology, came forward for
investing. So, the government provided them with local
monopoly and assured fair return through regulated price.
Thus regulation provided risk minimization for both sides. Both
regulation and deregulation make sense and one or other is
preferable under certain conditions [2].
With the advent of efficient combined cycle gas turbines, the
economies of scale condition in support of the vertically
integrated companies no longer existed. Also, large-scale
computerisation and automation of the processes led to the
reduction of manpower requirement. The monolithic vertically
integrated firms by then were suffering from huge human
inventories, inefficiencies, and unaccountability. By now, as the
technology is proven, finances were readily available; the
condition for granting monopolies no more existed. Apart from
the above, the economists argued that competition would
encourage innovation, reduce costs, improve services and bring
in customer focus. All these and other political compulsions led
to deregulation of the electric industry.
There are many terms being used in different contexts of
making the electricity industry competitive, like regulation,
deregulation, restructuring etc, which are briefly introduced
next.
1.2.1 Regulation
The same company provided generation, transmission and
distribution in the area of its monopoly. The industry remained
vertically integrated for more than a century because of the
following reasons.
To keep the system stable, it was considered that generation and transmission needed to be under
the command and control of single entity.
The natural monopoly aspects of economies of scale, site requirements for the transmission
corridor and network characteristics.
The natural monopoly aspects of economies of scale, space requirements, aesthetics etc., which
make the competition in the distribution
uneconomical.
The economies of scale of generation and integrated development of generation and transmission.
To safeguard the interests of the consumers, it was felt
necessary by the government to control the industry through
regulation. The regulated industry grew in size over the years.
The regulatory solutions are inefficient and have some
disadvantages. The regulator looks at the scenario post-facto
and it may appear that there are efficient ways of managing the
business. Hence the regulator may disallow the expenditure of
the utilities. Thus the utilities carry the risk of good faith efforts
disallowed. Even though the regulatory solutions are inefficient,
they are successful in safe guarding the interests of the
customers.
1.2.2 Deregulation
It is to remove entry/exit barriers to the trade and industry and
to remove controls on prices. This would be disastrous to the
consumers if deregulation was done without putting necessary
safeguards in place. To introduce competition in the electricity
major changes are required such as
Time slab-wise metering of most of the consumption (need not be most of the consumers) and pricing of
electricity during different time slabs are to be made
known from the market in real time on the web
page of the retailer/distributor so as to develop
customer response.
System operation should be separated from the trading of electricity.
Transmission (and distribution, in case of retail access) network should be separated from the
trading.
Remove entry and exit barriers for all the market participants i.e. generators, distributors, retailers
and consumers.
Just declaring the industry is deregulated and providing open
access cannot produce competitive markets. The UK had made
a law permitting competitive entry and requiring open access
from 1984 onwards; but since it did not provide the trading
arrangements there were no takers until the industry was
totally restructured in 1990 [1].
While deregulating the industry, reliability is the paramount
important factor that needs to be taken care of - reliability in
terms of transient stability, adequate capacity additions in
generation and transmission and distribution networks.
Competitive markets replace the regulatory control with that of
the market participants investment decisions. It will bring in
effective utilisation of the assets and at the same time may lead
to more congestion.
1.2.3 Decentralization
Unbundling of different functions of the vertically integrated
monopoly to make the utility more resilient is all about
decentralization. The decentralised model can work decently, if
it is designed properly. It is capable of delivering competition if
it includes market-based solutions. It certainly can be designed
poorly, as the California is a glaring example.
Electricity is a commodity so different from others, that it
remained logical to remain regulated for so long. The major
difference between regulation and competition is the
responsibility of taking risks, which provides incentive to
improve. The main risks involved are
Market demand and prices Technological developments or obsolescence Credit risk and Management decisions of investment, manning,
maintenance etc.
Under regulatory regime, customers take most of the risks and
rewards while under competition the owners are subjected to
risks and rewards.
During the last 10 to 15 years, electricity industry in many
countries is changing due to country specific reasons. In
developed countries while the main reasons for change have
been lower tariff, better services and consumer choice, in
developing countries the reasons have been capacity
augmentation, building efficient systems, and reasonable tariff.
However, restructuring this industry is harder than most people
think, because electricity,
cannot be stored (storing in High Voltage batteries and in pumped storage reservoirs entails high
costs).
is transported at the speed of the light over a fragile and interactive transportation network requiring
short term and real time coordination.
traces the path of least resistance and defies the planned transmission route allocation
follows unique set of laws of physics normally has low price elasticity of demand
The common feature of the decentralized trading model is that
the system operator must take into account the origin and
destination of contracts for scheduling and dispatching. The
system operator is not intended to facilitate spot market - she
simply schedules trades that have been arranged elsewhere,
whereas in the integrated model, the system operator makes the
trades automatically. Introduction of competition poses some
really difficult problems. Rational solutions depend upon
understanding these complexities and designing ways to
account for them [1]. Restructuring, Open access and
Deregulation are the tools used to introduce competition and
improve efficiency. The elements that need to be in place for the
markets to be competitive and work efficiently are
many buyers and sellers ensuring lack of market power to any individual utility
price responsiveness of demand and supply
liquid and efficient markets accurate and timely information to all non-discriminatory access to transmission and
distribution networks
Even though the competition theory and the theory of market
power holds that market power will solve itself by the entry of
new competitors, who will drive down the prices back to the
competitive level. In reality, it may not happen. A dominant
player can set the market price. If a competitor tries to enter
that territory, the dominant player can lower the prices, lower
than the competitor and scare him off. This will result in the
new incumbent falling flat due to lack of financial muscle or it
may lead to price wars.
If the competition is limited to the wholesale market and the
retail customers are charged at a price averaged over time, then
the retail customers where the actual load can be controlled will
not have any incentive to respond. So, while designing
competition, it is necessary that the model should be so built
that there would be information available in real time to all the
actors in competition and there would be incentive for all of
them to respond to the changing scenario in the grid in real
time. Advantage of competition is that the supply will be
reliable as lights go off only when the consumer wants them to,
given the price signal. The lack of customer response is what
worries about the reliability of supply. Adequate attention to
demand response results in flattening of the load curves and
would remove the need for capacity addition. This would
require metering with respect to the time of usage.
To illustrate the effect of load flattening refer to the following
example.
Electricity consumption per
month Rate per kWh Charges for the month
Hours Contracted Actual Contracted Spot As per
Charge
(Credit)
Usage
(kWh)
Usage
(kWh)
Diff.
(kWh) Price (Rs.)
Price
(Rs.)
Contract
(Rs.)
for
difference
(Rs.)
a b c d=c-b e f g=b*e h=d*f
00-04 200 250 50 3.50 1.50 700.00 75.00
04-08 300 400 100 3.50 2.00 1050.00 200.00
08-12 450 650 200 3.50 3.50 1575.00 700.00
12-16 1000 750 -250 3.50 4.50 3500.00 -1125.00
16-20 1100 850 -250 3.50 4.00 3850.00 -1000.00
20-24 350 500 150 3.50 1.50 1225.00 225.00
Total 3400 3400 0 11900.00 -925.00
Bill as per the contract = 11900
Charges for the extra usage = 1200
Credit for the reduced usage = -2125
Net charge / credit for
difference = -925
Total Bill = 10975
Table 1.1: Load flattening effect of TOD based pricing
Figure 1.1: Load flattening effect of TOD based pricing
The basic difference with decentralized model when compared to
the integrated model is that in decentralized model it ends up
requiring not only private markets for regular Electricity, but
also markets for congestion management, imbalances, ancillary
services, provision for reserves etc, which are explained later.
1.2.4. Restructuring
During 1980s, some economists started arguing that the
monopoly is to be removed to incentivise innovation, to operate
efficiently and to discourage unnecessary expenditures and
investments. That would require the vertically integrated
companies to unbundled [13]. The aim is to remove the
monopolies and to bring in competition. This is done by
separating some functions of vertically integrated entity,
combining other functions and sometimes creating altogether
new companies. This may lead to the loss of synergies and
economies of scale of the traditional monopolistic structure.
But, if efficiency gains could offset these losses then the
restructuring also known as unbundling will result in overall
gains. While restructuring, it would be prudent to retain the
natural monopolies; like having a single transmission and
distribution network in a particular area instead of having
multiple networks, which would result in duplication of the
assets without any apparent benefits. Therefore, the
restructured industry would still retain the regulated natural
monopoly of transmission and distribution networks while
competition would be introduced in generation and retailing.
1.2.5 Open Access
Open access means that everyone gets the opportunity to use
the wires without any discrimination. But indiscriminate access
to the network poses new challenges. In a vertically integrated
electrical industry, coordination of generation and transmission
was easy as all the assets are under command and control of a
single entity. In the competitive industry, new trading
arrangements have to be set up to ensure real-time coordination
[1]. This can be accomplished by complete separation of system
operations into an independent organisation.
In addition to the real-time coordination, open access requires
arrangements for long-tem control of the transmission. In a
vertically integrated industry, utilities themselves planned and
implemented the transmission along with the generation and
distribution. However, in the deregulated environment there are
challenges of transmission expansion, pricing the transmission
rights, providing access without discrimination and
coordination with different agencies involved.
The open access when extended to the retail markets is known
as customer choice, where customer can chose the supplier
and every supplier has access to the local distribution network.
1.3 Industry Classification
The industry can be differentiated in a number of ways and
different classifications can be used to identify the models.
There are different models in existence world over.
1.3.1 Classification based on trading model
This classification assumes continued monopoly over
transmission and distribution network and system operation.
The differentiating characteristic is how the Electricity is traded
in the industry.
a. Integrated model
This is the model, which prevailed for more than a century in
many of the markets and is still in practice in many nations. In
this model, the generation, its transmission, distribution and
sales are all integrated into a single monopoly, which is under
the control of single electricity entity. The utility charges
average tariff from the customer and often would not segregate
individual costs involved in each function, which led to
unaccountability and inefficiencies. The advantage of this
model is fairly stable and easy to understand electricity bills.
Figure 1.2: Vertically integrated monopoly business model
This model was in use many of the SEBs in India and is still in
vogue in some SEBs. All the functions of electricity generation,
transmission, distribution, sales and billing are integrated into
one entity. This model is losing its relevance in India with the
restructuring drive taken up in all the states.
b. Decentralized Business Model
The following is a representative structure in the deregulated
market. There are so many other models to choose from. It is
up to the policy makers to decide on the choice of the model.
Figure 1.3: Decentralized business model
In deciding the model, they have to understand the implications
of structural change, the need for institutionalizing new
arrangements and to address new set of complications. In the
wholesale competition model, the challenge is to address the
problems of the boundaries and devising contracts. The
challenge in the retail competition model is to develop the new
settlement system and transaction costs. However, retail
competition overcomes the shortcomings of the wholesale
competition model. Different models in decentralized model can
be pool model, competition at wholesale and retail level. These
are explained further.
i. Pool model
This is the model first used in United States and in United
Kingdom. This is a model of monopsony where a single
buyer would purchase the Electricity required from the
generators. In this model the independent generators
have no option but to generate and sell only to pool. The
Monitory Flow
existing utilities will draw from the pool, which has
complete monopoly over distribution companies and final
customers. The prices at which the generators sell the
electricity to the pool would either be determined by the
market regulator or the utility signs a long-term life long
contract with the generators. These bilateral contracts
can run in parallel to the pool operation.
The system operator would normally operate the pool.
This would follow a single auction formula. All the
generators would bid into the pool and the system
operator after running an optimisation algorithm would
decided which generator to run. The buyer has no option
of choosing the supplier. This is a limited form of
competition in the wholesale segment. The market
structure is based on long-term contracts and most of the
risks are transferred to the customer through these long-
term contracts. The challenge in this model is to decide
how to ensure profits to the generator. If the profits are
paid upfront, then the issue is to ensure to run the plant
when it is required. If the profits were paid with variable
charges, then the issue would be to stop the plant when it
is not needed. Normally this model will have two-part
tariff where in fixed charges are paid when the plant puts
in certain minimum number of hours of service over the
period. Variable charges would be paid based on the
electricity generated. A similar model was in existence in
India for its central sector power plants where SEBs have
share in these power plants. The states would pay fixed
charges for their share in each CGS and would pay
variable charges based on the electricity drawn from each
CGS.
The generators have no option but to sell their Electricity
at the regulated prices or at Market Clearing Price decided
by the Single Auction Model explained under head Power
Exchanges.
Figure 1.4: Pool business model
The pool model is similar to unit commitment and
economic dispatch. In traditional unit commitment and
economic dispatch the actual cost of the electricity is
considered but in deregulated environment, the price
curves are considered and the actual cost curves are
hidden from the knowledge of general public.
ii. Wholesale competition
In this model, the entire generation is deregulated and the
generators sell the electricity in competitive wholesale
market to discoms, retailers and large customers.
Allowing only large customers in the initial phase though
will thwart development of competition, will allow the
Genco Genco IPP IPP
STU Power Pool
Disco
Customer
Disco Disco
Customer Customer Customer Customer
market to stabilize and test the waters before introduction
of competition in the retail market as well. The
disadvantage with this model is that some of the large
customers may be too large and may thwart competition
from developing.
Figure 1.5: Wholesale competition business model
With restructuring of the Indian electricity industry, this
sort of model is evolving in all the states. With the
unbundling of the state electricity utilities, the emerging
scenario is going to appear similar to this model. Some
states are ahead and some are trailing in adapting to this
model.
iii. Retail competition
This is the ultimate model of competitiveness in the
electricity industry. Countries like Norway, Sweden,
Spain, Australia, New Zealand, United Kingdom and many
states of United States are trying to put this model in
Genco Genco IPP IPP
Disco
Customer
Disco Disco
Customer Customer Customer Customer
place. The greatest challenge in this model is education of
customers, who should be aware of the developments in
the markets and should be able to participate in the
market. Also, this model requires that appropriate
metering (time of the day metering), billing and settlement
process are put in place. The advantages of this model
are that it gives all the customers choice to choose the
supplier; competition in the wholesale as well as retail
markets. The disadvantage of this model is those
customers need to be metered on the time block wise, as
the price is volatile and keeps on changing on block-to-
block basis. This would result in unpredictable electricity
bills.
As in the case of the telephone service providers, there
may be a plethora of switchings between the service
providers. This model may lead to confusion in a less
educated society, as it will be difficult to decipher the
electricity bill. The smaller customers may prefer
predictable bills and value added services. The
transmission and distribution networks will be given open
access.
Genco IPP Genco IPP
Figure 1.6: Retail competition business model
It would require good amount of distribution automation
and sophisticated automation for dissemination of varying
prices of electricity over the period of time. This model
would also require consumer education, as the success of
this model depends on the extent of consumer demand
response to the supply price signal. With the exiting
infrastructure, it would be difficult to adapt retail
competition in the Indian market.
1.3.2 Classification based on contractual model
The market can be classified based on how the electricity is
contracted. It can be through a term contracts or through
Power exchanges or through pool. The pool model is explained
above and the remaining two are dealt with now. It is worth
mentioning here that the models are not mutually exclusive.
Any or all of them could co-exist.
a. Bilateral Agreements
Retailer
Customer
Retailer Disco
Customer Customer Customer Customer
Disco
In this model, individual buyer and seller would enter into an
agreement for exchange of electricity at agreed terms and
conditions without entering into pool arrangements. The terms
and conditions may be agreed through negotiations or through
competitive bidding. These contracts would then be informed to
the system operator for implementation. These contracts could
be Long term extending to the life of the plant or may be Short term valid for a period typically of less than twelve months. At times a combination of both in conjunction with pool purchase/
spot purchases are used which is known as Hybrid model. The advantage of this model is flexibility. It is not mandatory to sign
bilateral contracts or to purchase through pool. Customers can
choose the mode of purchasing power based on their
convenience and requirement.
b. Third Party Agreements
In this model, a third party (trader) would get the bids of power
from the suppliers and would offer the electricity to the needy
consumers at a negotiated price or on cost plus basis. The
supplier and consumer would be relieved of the effort of
identifying the counter party. The trader would act as an
intermediary for such trades and she would secure the
payments for the electricity traded.
c. Power Exchange
This is the model normally used to trade commodities, which
operates more or less similar to a stock exchange. The sellers
and buyers would inform the Power Exchange, the quantity and
the price at which they are willing to exchange electricity. This
is known as Double Auction Model. The point of intersection
of demand and supply would determine the Market Clearing
Volume (MCV) and Market Clearing Price (MCP).
Figure 1.7: Double sided auction on Power Exchange
In other model, known as Single Auction Model, the sellers
may indicate the quantity and the price at which the electricity
that the generator would be willing to sell. The system operator
would arrange these bids in ascending order and the cut-off
point where the last unit of demand is met would determine the
MCP.
Double-sided auction model
MCV
MCP
Volume in kWh
Price in Rs. /kWh
Single sided auction model Price in Rs. /kWh
Demand
Supply
Figure 1.8: Single sided auction on Power Exchange
In this model, there are chances of price rigging through
strategic bidding.
Figure 1.9: Merit order clearing of Power requirement
It is explained with help of the above diagram.
Anticipated Demand
MCP
Volume in kWh
Merit Order
Gen
1
Gen
2
Gen
3
Gen
4
Gen
5
Gen
6
Gen
7
Gen
8
Gen
9
Gen
10
Gen
11
Gen
12
Gen
13
Gen
14
Gen
15
Supply
Rs./kWh 4.0 3.5 3.0 2.5 2.0 1.5 1.0 0.5
MCP = Rs.2.75/kWh
To meet the demand, the system operator would schedule full
generation up to generator 11 and partial generation on
generator 12.
However, say a particular utility owns generators 2, 4, 5, 9, 11
and 15. It can strategically bid out one of its generators forcing
the system operator to acquire more costly power from say
generator 13. This would result in increased MCP and hence all
the generators that are scheduled will be benefited by the extra
contribution. Scenario under such situation is depicted in the
next drawing.
Strategic Bid
Gen
1
Gen
2
Gen
3
Gen
4
Gen
5
Gen
6
Gen
7
Gen
8
Gen
9
Gen
10
Gen
12
Gen
13
Gen
14
Gen
15
Gen
16
Gen
11
Figure 1.10: Scenario under strategic bidding by a generator
Generator 11 is bid out of merit order, yet benefiting the utility
as a whole.
The disadvantage in this model is that price rigging can be done
by shifting the low cost generator out of service. The slope of
the price curve is an important determinant of such behaviour.
Rs./kWh 4.5 4.0 3.5 3.0 2.5 2.0 1.5 1.0 0.5
MCP = Rs.2.95/kWh
The steeper it is, the more likely it is that economic withdrawal
is profitable [1].
In this model also, the supplier and consumer would not know
with whom they are dealing with. The bids on the power
exchange can be submitted for Day Ahead market, in which case the bids would be submitted at 10:00 hrs and the deal
would be finalised by evening to be implemented from 00:00 hrs
of the next day. There can be bids for Intra day markets, which will be submitted any time upto an hour in advance,
which will be used to make adjustments during the day of
operation. The markets can be a combination of the above two.
1.3.3 Classification based on system operators
Electricity needs short-term coordination (Day ahead, intra day
and real time coordination). The system operator has to ensure
system security and reliability and she has to respond within
seconds to get plants to change their output if an overload
threatens [1]. Open access to the transmission and non-
discriminatory system operations are the two important features
for competition. These are the two major sources of dispute.
Another area of dispute is the responsibility of expanding the
transmission network to meet the future requirements. The
system operator may need more transmission lines for better
stability and availability of requisite transmission capacity. On
the other hand, the transmission company may not be
interested in investing due to lack of adequate returns on the
investment.
As it would not be economically viable and environmentally
feasible to build new assets, it would be ideal to operate these
assets to their maximum limits.
a. Transmission System Operator (TSO)
In this model, the system operator would own the transmission
assets. This is the model adopted by most of the European
countries in conjunction with pool operation. All the
transmission assets are at the command and control of the
system operator.
In such a model, the responsibility of providing open access to
all the participants and developing the network lies with the
TSO. During real time congestion, the system operator has to
reschedule the transactions to safeguard the security of the grid
and safety of her assets. The system operator may be reluctant
to reschedule too often. So, she has incentives to calculate
available transmission capacity on a fairly conservative basis
[1].
The Nord Pool adopted TSO model where individual countries
have their independent transmission networks and manage
them. These networks are coordinated under Nordel.
b. Independent System Operator (ISO)
This is the model adopted by many markets in United States,
Canada and Australia etc. In this model the system operation
and market operation are combined into one at Independent
System Operator (ISO). The ISO will have no assets and will
have no commercial interest in the activities of the market
participants. However, the ISO would operate the imbalances
market and ancillary services market. She will have command
over all the market participants, empowered through legislation.
In a competitive world the system operator need to be
independent for discharging the following responsibilities.
To ensure equal opportunities to all the participants for accessing the network.
To ensure integrated operation of the grid and maintaining grid security and stability at all points of
time.
Assess and monitor the demand supply situation and acquire the differences from the balancing markets.
Acquire ancillary services as and when required. Manage the network congestion.
1.3.4 Classification based on transmission ownership
The transmission assets can be developed by a monopoly
because of its characteristics as a natural monopoly. However,
this monopoly could be limited to a region, a state or a territory
or the monopoly can be extended to the whole of the country or
region of operation. If the entire country is given a national
monopoly then it is called National Monopoly. The country may be divided into number of regions and Regional Monopoly may also be granted. The development of new transmission
capacity would be the responsibility of the national
transmission utility. In such a case, regulator or central
planners should oversee the investments in the transmission
sector to ensure that adequate transmission capacity is built to
meet the future transmission requirements and the stability
considerations.
To bring in competition in the transmission sector and to
encourage innovation and competition, transmission sector may
open to multiple players with open access. In such a case, the capacity augmentation would be in the corridors where the
rate of return is attractive to the investors. The system may
need augmentation of transmission capacity for the reasons of
system considerations. Such investments would not be
forthcoming incase of competition in transmission.
1.3.5 Classification based on number of participants
This type of classification is based on the number of
participants operating in the market, from the sellers side as
well as from buyers side. If there are many sellers and single
buyer as in the case of the pool, perfect competition may exist in
the sellers market while in the buyers market, it will be a
monopoly. Different models are briefly described here under.
a. Monopoly
In this model, a single entity will have the control over the entire
market in the identified geographic territory/ jurisdiction.
Normally the monopolies will either lie with the government or
the government will have a supervisory control over the entity to
ensure that the end consumer interests are protected. When
the monopoly situation is created in the buyers market it is also
known as monopsony.
b. Oligopoly
In oligopoly, the competition is limited between few parties. The
oligopoly competition can exist either in sellers market or in
buyers market. In this market there are chances of price wars,
game plays or formation of cartel. If there are only two
participants in competition then the market is known as
Duopoly.
c. Perfect competition
In this type of competition there will be many number of market
participants each with a small share of the business that none
of the participants will have the market power. This is the ideal
market situation and it is very difficult to build a perfect
competition, as there will be some or other forms of market
imperfections.
Chapter 2: Factors influencing trading and competition
2.1 Introduction
Before competition is introduced into electricity markets, it is
essential that measures to support competition need to be
taken. The basic requirements of competition are providing
1. Adequate transmission capacity at appropriate price
without any discrimination,
2. Provision for imbalances management
3. Congestion Management
4. Providing ancillary services,
5. Ensuring the grid security and stability and
6. To hedge the risks involved in the business.
Transmission pricing and system operation thus finds
importance in bringing competition into play.
2.2 Transmission pricing
For introducing competition, it is necessary that the
participants are aware of the commodity (electricity) price and
the infrastructure (transmission) price. The knowledge about
the price and the charges involved in bringing the commodity to
the place of consumption will help in decision-making and will
produce better trading. Apart from the information about the
pricing, open access to the transmission network without any
discrimination is essential. The critical elements in providing
open access to transmission system are charges for
transmission in case of no congestion and charges for the
transmission to mitigate or manage the transmission
constraints. There are several ways of achieving these
objectives. The charges for congestion management are dealt
with under the heading congestion management. Different
methods of transmission pricing are adopted to suit the local
conditions, which are delineated here under.
2.2.1. Flat fee
This is the simplest possible transmission pricing. It can be
easily understood and the fee would be stable over the period.
The total costs of fixed charges and operation and maintenance
charges are distributed amongst all the customers who use the
transmission system.
2.2.2. Postage stamp method
This is also fairly simple way of transmission pricing.
Irrespective of the distance involved all the users would pay the
charges on the proportionate use of the transmission capacity.
In India, the postage stamp method of transmission pricing is in
use. The postage stamp pricing is used among the beneficiaries
of the region and the regional price of the transmission capacity
in Rs./MW would be worked out and billed according to the
contracted amount of electricity transmitted.
2.2.3. Mile MW method
This is a little complicated but reasonable way of pricing the
transmission capacity as both the quantity and the distance
over which the electricity is transmitted is taken as basis for
calculating the transmission charges payable by the individual
customer. The model cannot take into account actual circuit
miles of transmission line usage. Hence, notional distance of
power transmission is considered as the electricity would flow
based on the network configuration and system dynamics,
which cannot be accurately predicted.
2.2.4. Contract path method
This method uses the assigned path of electricity transportation
as the basis for calculating the transmission pricing. However,
the electricity is such a commodity that it would be difficult to
assign a path of transmission of electricity. The electricity
follows its own distinct and unique laws of physics traversing
the network following the path of least resistance.
2.2.5. Point of Connection tariff
In this method the existing total transmission charges for the
region or a state where the tariff is being introduced is
accounted for. Whatever may be the present method of
transmission tariff, the present level of revenue from
transmission is assured in POC tariff. In the new tariff, the
tariff per MW at the highest voltage level is calculated based on
the investments made and the amount of power transmitted.
Then the same at a lower voltage level it is calculated. The
calculations are done for the entire network till the lowest
voltage level is reached. Now for every node in the network the
transmission tariff is fixed based on the layers of transmission
network used. This will be a transparent and stable
transmission pricing.
2.3 Imbalance Management
Whatever model is adopted, the notion that the transactions
should be physically scheduled so that buyers and sellers
should be matched is a fiction. There are bound to be difference
between the contracted amount of electricity and the actual
delivery/consumption. This imbalance between the contracted
quantity and the real time requirement need to be bridged to
ensure the stability and the security of the transmission
network and to ensure the quality of electric supply.
In an integrated model, the system operator owns resources
necessary to provide this service. In a decentralized model, the
system operator has to acquire these resources on commercial
basis. The balances can be acquired either at regulated prices
or at market-based prices. In case of an integrated model,
arbitrary imbalance prices invite gaming. Consumers may
prefer imbalances rather than contracting at more expensive
prices.
A similar trend is seen in the Indian market also. Some
consumers prefer not to schedule their share of electricity and
instead rely on the UI power to meet their demand. It is better
to determine the imbalance price based on the market
requirements. This sends the right signal to the contracts
market and for the long-term investments for the generation.
The imbalance market gives flexibility for the generator and
consumer to deviate from the contracted quantity of electricity
as the imbalances are appropriately priced instead of punitive
prices.
2.4 Congestion management
In the pool system all the consumers would pay a common
price, MCP as mentioned earlier. When the markets are thrown
open to competition, all the buyers would seek to benefit from
the cheaper sources of electricity. This may result in congestion
over transmission network. This may create market power for
some of the generators to exploit the opportunistic situation.
In vertically integrated utilities, the generation and demand are
fairly stable and generation and transmission facilities are
augmented in a coordinated way. Also, as the system will be
under control and command of a single entity, the assets are
controlled effectively and the possibility of congestion is
minimal. In a competitive environment, the supply and demand
could vary widely with the market forces and may lead to
congestion. The congestion is managed through different ways
listed under.
Price Area Congestion (PAC) management Counter trade Pro rata reduction in capacity allocation Bidding for the residual capacity Nodal / Zonal pricing Constrained unit commitment model
However, during the phase of congestion management, the
system operator calls for additional generation in one area and
reduced generation in another area or reduced load in one area
and increased load in another area. While doing so, however,
no entity would like to lose on commercial front. As such, the
arrangement should be able to answer the issue.
2.4.1. PAC Management
Whenever, congestion is apprehended, the system operator
declares that the system is split into different price areas across
the congestion area, with higher pool prices in the area
downstream of congestion and lower prices in the area
upstream of the congestion. This will relieve the congestion on
the transmission network.
The advantage of this method of splitting the market into
different price areas is that it gives a price signal to the
generating companies to add new capacities in the area of
higher pool prices thus increasing the competition and
ultimately reducing the overall price in the long run.
2.4.2. Counter Trade
This method is used incase of real time congestion on any
transmission corridor. The system operator will offer a counter
trade to the upstream of the congestion to the extent that the
transmission corridor is relieved of congestion. The counter
trade is a notional trade, which will result in reduced generation
from the upstream of the congestion so that generation
elsewhere will be picked up to balance the system and relieve
the congestion simultaneously. The charges towards this
counter trade will accrue towards the charges of system
charges.
2.4.3. Pro-rata reduction
In case of congestion, all the participants drawing power on that
corridor will be given a pro-rata reduction of the schedules so
that the drawl on the corridor reduces to relieve the congestion.
2.4.4. Bidding for Residual Transmission Capacity
At present this method is being used in India for usage of the
residual transmission capacity left out after catering to the long-
term bilateral contracts. All the consumers would contest for
the remaining capacity available in transmission corridors of
their interest. In the absence of any congestion, as mentioned
earlier in transmission pricing, the corridor would be made
available to all the short term customers at 1/4th of the price for
the long term customers arrived at by postage stamp method.
For short-term customers, all the applications received upto
19th of every month would be bunched and access would be
allowed on first-come-first-served basis, subjected to the
availability of ATC [3]. However, in case congestion is
anticipated, then revised bids would be sought from all the
customers. These bids would be arranged in descending order
and the customers who are willing to pay higher charges would
be allowed access. However, the highest bid is capped at 5
times the floor price in case of inter regional transmission
system and 2.5 times the floor price in case of intra regional
transmission system. In case the system operator notices the
congestion in real time, due to any constraints, she would
advise a revised transmission capacity allocation by reducing
the schedules in pro-rata basis.
2.4.5. Nodal / Zonal pricing
In this method, the system operator would obtain the cost
functions of the generators and bids of consumers and would
run an optimisation algorithm, which will take into
consideration number of constraints and derive at the optimum
solution to meet the demand. In case of congestion, this
algorithm would divide the entire grid into nodes and would give
nodal prices. Or the system could be divided into number of
zones and would give the price in each zone. The zone with
higher generation would be priced low and the zone with
shortage in generation would be priced higher. In case of no
congestion, the entire system will have a single price.
2.4.6. ATC with Constrained unit commitment model
The system operator would schedule all the regular transactions
and then would indicate the available transmission capacity in
each transmission corridor for each time period of the day. This
information would be displayed on the web site of the system
operator. A similar system namely OASIS (Open Access Same-
time Information System) is in vogue in PJM interconnection
and in some other US markets. Customers would access this
OASIS and find out whether any transmission capacity is
available for the transaction they are planning. As the ATC
becomes scarce, the price of the ATC in that corridor goes high.
This would give the price signal to the market for investments in
that area. Though a little complicated this would be a
transparent system of offering open access without any
discrimination.
The model is useful in centralised dispatch model like PJM
market, NYISO etc. The unconstrained unit commitment will be
derived based on the bids and offers. If any congestion is
noticed then the constraints are introduced into the algorithm
to arrive at the economic dispatch with constraints known as
constrained unit commitment.
2.5. Ancillary Services
In a vertically integrated monopoly, all the services are bundled
in one and the charges are billed as transmission charges.
However, when the electricity is deregulated and open to
competition, all the services would be separated, called for
separately and charged. The ancillary services includes
VAR compensation Balancing power Primary response Secondary response Spinning reserve Black start facility Peaking power Standby services Load following etc.
2.6. Grid Security
The system operator should ensure that the grid is stable and
secure. The system operator should exercise such command
and control over the system that she displays transparency and
non-discrimination in dealing with different customers. The
system operator should be empowered to give instructions in
the interest of the grid.
2.7 Hedging risks
The markets are known for their volatility and electricity market
is no exception. It has been observed that competition has
introduced uncertainty in the market and the price volatility has
increased tremendously in the absence of price caps. Price
caps, however, are an inefficient way of managing the exchange.
Apart from price risks, there may be risk of supply, payment
default, market risk, congestion, inadequate information and
lack of experience. In order to hedge against these risks,
transparent financial market needs to be developed where
products like futures, options, forward contracts etc., will be
available to hedge the risk.
The marketplace for electricity need to be liquid, where many
buyers and sellers could access each other easily and have the
access to market information. Also, the market needs to be
efficient where participants ideally cannot predict which way the
prices will move. The electricity market should be equipped
with proper risk hedging instruments, taking into consideration
the special requirements of the electricity business. Even
though various derivatives are used in the electricity markets,
the following are the most widely used instruments. They are
explained in brief. However, it is to mention here that the
derivatives markets are not intended for physical delivery of the
product. Normally less than 10% of the derivative instruments
will result in physical delivery of the product, while the rest are
used to hedge the risk through the difference of the derivative
price and spot market price. The derivative instruments are
traded in the secondary market also, making them liquid assets.
2.7.1 Futures
The futures market is a type of forward market that takes place
on an organised exchange. It is a standardized contract to
exchange the commodity at a predefined fixed future date for a
negotiated price. The standard terms and conditions of the
futures contract make it easily tradable. In an efficient and
transparent market the difference between the spot price and
the futures contract will always equal to the cost to carry. As
the maturity day approaches, the future and spot prices
converge [2].
2.7.2 Options
While the futures contracts are binding to exercise the right, the
options contract provides the holder of the contract the right,
but not the obligation, to buy or sell the commodity at an agreed
price known as strike price. The holder pays a fee / premium
upfront. Whether or not the option is not exercised, the fee paid
will not be returned. The holder will exercise the option, if the
spot price is favourable compared to the option price. The
options are two types. If the option gives the right to purchase
the commodity, then it is called call option and if it gives the right to sell the product, then it is called put option.
2.7.3 Forward contracts
This contract is similar to futures contract with the difference
that the forward contracts are tailor made unlike futures. These
tailor made contracts are between two parties and normally
culminate in physical delivery. These are not traded on
exchanges and hence are not liquid. These are short term in
nature and are used for managing the price risk where the
market prices are volatile and to off set the balancing
requirements in real time.
2.7.4 Swap contracts
The swap contracts are signed between two parties to hedge
against the volatility in the price. The swap would enable the
party to isolate itself from the volatility so that it can
concentrate more on the business while the swap provider who
is a financial expert in the business of providing the risk cover
will manage the swap contracts, by swapping the variable price
with a fixed price.
2.7.5 Contract for Differences (CFDs)
In pool system, generators and consumers may enter into long
term fixed price-hedging contracts also known as Contracts For
Differences (CFDs). The generators want to hedge the risk of
pricing dipping too low lesser than the marginal cost of the
generators while on the other hand the consumers want to
hedge the risk of spot prices going through the roof. CFD would
hedge the risk for both the parties. If the spot price dipped low,
the consumer would pay the difference to the generator while if
the prices soared, the generator would refund the difference
between the strike price and spot price.
This way a single contract would hedge the price volatility for
both the generators and consumers.
2.8 Choice of System Operator models
To keep the system stable, it was considered that generation
and transmission needed to be under the command and control
of single entity. However, with the introduction of the
competition, it became apparent that it is not required that the
system need to be vertically integrated. In restructured
markets, the system operator can be a TSO or an ISO. TSO
having the ownership of transmission assets under her control
will be at ease while controlling the grid. However, due to
ownership of the transmission assets, she will be compelled to
load the transmission assets conservatively. Thus TSO model
will limit the optimum utilisation of the transmission assets.
On the other hand, ISO will try to optimise the system
operations and will try to load the transmission assets optimally
simultaneously ensuring the security of the grid.
Apart from the above, when there are multiple owners of
transmission, it will be prudent to have an independent system
operator so that there is level playing field for all the owners of
the transmission.
2.9 Choice of trading models
While it is agreed that the monopoly is not a competitive model,
if conditions in a country warrants continuing with the
monopoly due to reasons of social conditions, the monopoly may
also work well in the given circumstances. However, the
challenge would be do ensure that a system is put in place to
make people accountable for their deeds and efficiencies are not
lost due to bureaucracy.
On the other front pool model suits those countries where there
is a need to bring competition in a limited way and continue
with the retail monopoly where the competition may not yield
better returns compared to the expenditure made in putting
competition to work in the retail market. The pool model also
helps in retaining the control over the market by regulating the
pool operator.
With the competition in wholesale market, the disadvantages of
monopsony could be eliminated in this model. Thus generators
are also not put to undue disadvantage as they have choice of
selecting their buyers. Furthering competition will result in
competition in the retails market where customers have real
choice. However, it is to be ensured that the retail competition
doesnt bring into too many complications in the operation and
the gains of introducing retail competitions far outstrip the
costs involved.
2.10 Choice of contracts
The bilateral contracts provide advantage of price stability and
predictability for both the generators and consumers over long
periods of time. While major requirements of electricity can be
met through these bilateral contracts minor adjustments in the
electricity requirements can be met through short term trading
contracts. The final fine-tuning of the electricity requirements
at the real time can be done in hour ahead or spot markets
through power exchange. The advantage of this model is
flexibility. It is not mandatory to sign bilateral contracts or to
purchase through pool. Customers can chose the mode of
purchasing power based on their convenience and requirement.
2.11 Choice of transmission ownership
The national monopoly of transmission provides with the
advantage of planned development of the transmission network.
It will also help in avoidance of duplication of assets. However,
national monopoly may go against the very premise of bringing
competition and efficiencies into the system.
Similar will the case with the regional monopoly as well as state
level monopoly. We may continue with the state level monopoly
for development of intra state transmission network. For
interstate and national transmission development, we may opt
for private transmission licensees; all providing non-
discriminatory open access. This is in line with the national
electricity policy. However, while adopting such a model, we
may have to have a central planning agency in the form of CEA
to plan approve the transmission interconnections for a
coordinated development of the network.
2.12 Choice of transmission pricing
The flat fee method is too primitive and the charges will not
reflect the usage of the transmission assets. On the other hand,
the contracted path method is a theoretical concept as it is well-
established fact that electricity flow cannot be assigned a
particular transmission corridor. The pricing of postage stamp
method though simple will not reflect the actual usage of the
transmission assets. It would be better if the transmission
pricing were based on the utilisation of the transmission assets.
The Point of Connection transmission pricing would better
reflect the philosophy. As such it would be an efficient way of
allocation of transmission costs to the users of the transmission
network.
Chapter 3: Electricity markets around the world
3.1 Introduction
The rationale for development of internal electricity markets
may be classified as legal, economic, technological and strategic
aims. The reasons may be different for different countries and
may be combination of several reasons.
3.1.1 Legal rationale
World over trade barriers are being removed. European court of
justice has held that electricity is a good within the meaning of
European treaty. Freedom of movement of goods is to be
ensured. However, due to public service value, electricity is
treated a bit delicately. Nevertheless, obligation to remove the
trade barriers is a matter of primary law.
3.1.2 Economic rationale
Global competitiveness depends on lower energy costs. The cost
differential results from the tax treatment (Danish government
imposes 142.5% tax on domestic sector while it is 8% in UK),
absence of competitive energy technologies used (Coal in
Germany to Nuclear in France), different pricing policies used
(France subsidies industrial consumers from domestic
consumers while it is the opposite in Germany).
With liberalisation, management may concentrate on short-term
profits and ignore the long-term capacity additions and R&D.
Hence gains in productive efficiency may offset losses in
dynamic efficiency.
3.1.3 Technology Advances
Due to disruptive technological advances, monolithic production
facilities with high sunk cost are becoming uncompetitive with
advances in gas turbine technologies and fuel cells. EHV grids
may become obsolete and distributed generation with miniature
fuel cells may replace them.
3.1.4 Strategic Aims
Dependence on external sources of energy requirement has
shown its disastrous effects during oil shocks. Strategic aim is
to have a coordinated energy policy to reduce the impacts of
external energy markets. The ultimate aim may be to ensure
energy security or to utilise the energy sources optimally or to
achieve self-reliance for the energy requirements or to utilise the
natural resources like water resources for optimally for energy
requirements and irrigation purpose. The strategic aim differs
from country to country.
3.2 Developed Electricity Market Models
By the time deregulation started in developed countries, already
they have established a well functioning and quite efficient
electricity system. In developed countries, the driving force
behind deregulation has been to provide customers with
electricity at lower prices and offer them a greater choice of
choosing their supplier pressure from small players in the
business to reduce the control and power of large state-owned
utilities.
The most discussed deregulation has been the England and
Wales market, with growing interest in the Nordic countries
model and much attention have been paid to actions in the
United States, especially in California, New York and PJM
Interconnection. California has been considered as a model
market to which others made reference. But perceptions about
the California market are now completely changed after
California crisis. Now lessons learnt from California electricity
market have strong influence on future policy and on the
evolution of other electricity markets worldwide. Hence in this
report, some developed electricity markets have been discussed
like England & Wales electricity market of UK, Nord Pool of
Nordic electricity market, California, PJM and New York
electricity markets of US. All these market models have
different characteristics and different trading arrangements.
3.3 England and Wales
3.3.1 Introduction
In United Kingdom (UK), the electricity industry was under
monopoly of Central Electricity Generating Board (CEGB),
generating and transmitting electricity. CEGB had to purchase
from British companies and couldnt seek better terms available
abroad. It produced, bought, sold and delivered electricity to 12
Area Boards. The Area Board in turn had monopoly in their
respective territory.
3.3.2 Phase I of reforms
During 1980s, with the experience of privatizing telecom and
gas monopolies, Conservative government led by Margaret
Thatcher published government white paper on setting out the
new structure for electricity. To create competition, CEGBs
generation was separated from its transmission. The
transmission is renamed as National Grid Company (NGC).
Generation is divided into three companies, National Electric
(now Innogy), Powergen and Nuclear Electric (later renamed
after privatisation as British Energy). The 12 Area Boards were
privatized and known as Regional Electric Companies (RECs).
The RECs have monopoly in one area while 2nd tier suppliers
can supply these areas bringing in competition. RECs were
thus under substantial competitive pressure.
3.3.3 Pool system
Then pool system was introduced. Licenses were given to
parties with sound financials. Half an hourly price bids by
generators were introduced. Demand is estimated by the NGC
and Optimal Power Flow algorithm would decide the Market
Clearing Price (Single auction method). The Optimal Power Flow
algorithm would take into consideration other variables like
operating flexibility, fixed price, variable price, standby charges,
startup charges, governor response, price for primary response
and secondary response (operating margins) and price for
peaking generation and derive the Pool Purchase Price (PPP).
Pool Purchase Price (PPP) = System Marginal Price (SMP) + CE
Where,
Capacity Element (CE) = LOLP (VOLL-SMP),
Where,
LOLP = Loss of load probability
VOLL = Value of load loss
Pool Sale Price (PSP) = PPP + Scale-up margin
SMP takes into consideration fixed price, operating price and
start-up price. As LOLP increases, the CE gives a price signal to
the market to attract more investments in to the capacity
addition.
Inspite of the best efforts and estimates, the actual demand
differs. As PPP is based on the estimates of demand, the model
calls for additional payments based on actual like reserve
capacity, capacity held due to transmission constraints,
generation beyond schedules to meet the consumption.
In pool system, generators and consumers used to enter into
long term fixed price-hedging contracts also known as Contracts
For Differences (CFDs). The CFD used to be the difference
between the strike price and PPP.
The pool system resulted in escalation of electricity prices while
the fuel prices dipped. Consumer surplus was encashed by the
shareholders and the management was rewarded by stock
options.
3.3.4 Regulatory Regime
To facilitate streamlining the industry, regulator is instituted by
enacting Electricity Act 1989. The objectives of the regulator
had been to
Regulate electricity prices Promote competition Induce new capacities Ensure health and safety of employees Protect environment / society Ensure stable power supply
3.3.5 Wholesale market
Due to technological improvements and the cheaper fuel prices,
many gas based Combined Cycle Gas Turbine (CCGT) plants
came up in UK. Gas units operate most efficiently when
operated continuously (with cycle efficiency as high as 60%) and
hence would bid low to remain in operation. Peaks were met by
expensive coal power plants. So, often the SMP is set by the
coal power stations. Hence, oligopoly situation prevailed in the
electricity market.
3.3.6 Retail market
Retailing and distribution is in the hands of the monopolistic
RECs. However, the second tier suppliers comprising of
generators and other RECs provided competition. This helped
in improving the service offered to the consumer and service
response time.
The ma