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Electricity market: the story on HearLore | HearLore
— Ch. 1 · The Monopoly Era —
Electricity market.
~5 min read · Ch. 1 of 6
In the 1950s, France operated a nationwide government-owned vertically integrated company. Italy followed this model with its own state-run utility structure. Greece and the Republic of Ireland also maintained similar centralized systems during that decade. The United Kingdom established a Central Electricity Generating Board to manage generation and transmission. That board left distribution decentralized across fourteen separate electricity boards. Germany combined regional integrated companies with municipal distribution networks. Japan created ten regional vertically integrated monopolies to serve its population. Norway kept electricity supply mostly at the level of municipalities. The United States developed a complex mix of privately owned and government-owned entities. Hawaii had only privately owned utilities while Nebraska relied on public ownership. The Tennessee Valley Authority became the largest federally owned generation company. Los Angeles Department of Water Power remained city-owned. These diverse structures shared very little reliance on competitive markets. No formal wholesale markets existed for these early systems. Customers could not choose their suppliers in any of these regions.
Deregulation Dawn
Chile became a pioneer in deregulation in the early 1980s. A law passed in 1982 codified changes started in 1979. Joskow and Schmalensee published Markets for Power: An Analysis of Electrical Utility Deregulation in 1983. This influential work popularized the new market approach to electricity in the US. The UK Energy Act of 1983 made provisions for common carriage in electricity networks. This enabled choice of supplier for electricity boards and very large customers. The concept was analogous to wheeling in the US. Distributed energy resources inspired innovative electricity markets emerging from hierarchical deregulated structures. Local flexibility markets now allow Distribution System Operators to procure services from assets linked to their distribution system. Aggregators represent multiple distributed energy resources as upstream entities. Tsaousoglou, Georgios, Juan S. Giraldo, and Nikolaos G. Paterakis reviewed models for local electricity markets in Renewable and Sustainable Energy Reviews in 2022. Jin, Xiaolong, Qiuwei Wu, and Hongjie Jia examined clearing methods in Applied Energy during 2020. These entities act as aggregators depending on asset characteristics.
When did France operate a nationwide government-owned vertically integrated company?
France operated a nationwide government-owned vertically integrated company in the 1950s. This system included state-run utility structures similar to those maintained by Italy, Greece, and the Republic of Ireland during that decade.
Which country became a pioneer in electricity deregulation in the early 1980s?
Chile became a pioneer in deregulation in the early 1980s with a law passed in 1982 codifying changes started in 1979. Joskow and Schmalensee published Markets for Power: An Analysis of Electrical Utility Deregulation in 1983 to popularize this new market approach.
What regions does PJM Interconnection cover with nodal pricing?
PJM Interconnection applies nodal pricing throughout its service territory covering Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, West Virginia, and the District of Columbia. These states fall under the jurisdiction of this specific Independent System Operator.
Why do electricity retailers enter hedge contracts with generators?
Electricity retailers enter hedge contracts with generators to protect against price volatility and uncertain consumption volumes. Simple fixed price forward contracts for physical delivery represent one common form used to manage these risks.
When did the California electricity crisis occur due to flawed retail competition regulation?
The California electricity crisis occurred during 2000/2001 due to flawed retail competition regulation. Incumbent retailers faced high spot prices without the ability to hedge against these costs during that period.
The Midcontinent Independent System Operator uses locational marginal pricing across hundreds of nodes. PJM Interconnection applies nodal pricing throughout its service territory covering Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, West Virginia, and the District of Columbia. ERCOT operates a centralized market since 2010 with nodal pricing in Texas. California ISO maintains centralized operations using nodal pricing. ISO New England implements nodal pricing with generator nodal pricing modifications. Nord Pool operates a decentralized market without zonal pricing in Nordic and Baltic countries. Great Britain switched to decentralized zonal pricing in 2001. Germany adopted decentralized zonal pricing. Ireland moved to decentralized zonal pricing in 2018. Spain and Italy use semi-decentralized regional pricing. The National Electricity Market covers five regions across Australia. Chile employs cost-based pricing instead of nodal or zonal systems. The US had weaker transmission networks leading to centralization differences from Europe. European markets generally moved toward decentralization while North American markets went through centralization. Political considerations sometimes make it unpalatable to force consumers in different nodes to pay different prices.
Frequency And Stability
The utility frequency must stay at either 50 hertz or 60 hertz to prevent equipment destruction. Many units automatically disconnect if out-of-bounds frequency occurs triggering potential blackouts. Frequency control markets provide specialized services separate from wholesale electricity pools. These markets incentivize provision of frequency raise services or frequency lower services. Rapid provision of extra electricity generation matches supply and demand more closely. Spinning reserve, non-spinning reserve, operating reserves, responsive reserve, regulation up, regulation down, and installed capacity are all ancillary services. Markets for power-related commodities ensure reliability through these mechanisms. The system operator acts to add or remove generation or load if frequency falls outside a predetermined range. In the United States, seven Independent System Operators manage transmission grids for over 60 percent of country power supply. These operators run security-constrained economic dispatch algorithms every 5 to 15 minutes. Ancillary services are often co-optimized with energy in both day-ahead and real-time markets. This ensures most efficient use of generation capacity for maintaining system frequency and stability.
Hedging Volatility
Electricity retailers enter hedge contracts with generators to protect against price volatility. Simple fixed price forward contracts for physical delivery represent one common form. Contracts for differences allow parties to agree on strike prices for defined time periods. If resulting wholesale price index exceeds strike price, generator refunds difference between strike and actual price. Retailer refunds difference to generator when actual price is less than strike price. Swing contracts, virtual bidding, financial transmission rights, call options and put options trade in sophisticated markets. Price spikes occur hard to predict while price steps happen when fuel positions change long periods. Volume risk denotes uncertain volumes or quantities of consumption or production. A retailer cannot accurately predict consumer demand more than few days into future. Producer cannot predict precise time plant outage occurs or fuel shortages arise. Extreme price and volume events show common correlation. Price spikes frequently occur when producers have plant outages or consumers peak consumption. Introduction of substantial intermittent power sources like wind energy affects market prices.
Crisis And Shortage
California electricity crisis occurred during 2000/2001 due to flawed retail competition regulation. Incumbent retailers faced high spot prices without ability to hedge against these costs. Independent Energy went bust in the UK owing £119 million in customer bills. The Enron debacle caused slow down in pace of change across regions. Major transfer payments for capacity reached as high as 47 percent of new unit revenue in US by 2018. Annual costs to consumers in New England calculated at $3 billion during FERC hearings on NEPOOL market structure. Wholesale trading allowed substantially better use of generation facilities but departures from costs increased. Deregulated nuclear and coal-fired plants outperformed vertically integrated peers. Gas-fired ones did not show same performance advantage. MacKay and Mercadal analyzed US market between 1994 and 2016 finding deregulated utilities realized significantly higher prices. They confirmed lower wholesale costs but found double extraction of profit margin by two vertically separated companies. All existing wholesale markets rely on offer caps preventing suppliers from fully recovering investment into reserve capacity through scarcity pricing. This creates missing money problem for generators needing incentives to build infrastructure used only during shortages.