Now showing 1 - 4 of 4
  • Publication
    Integrating European Electricity Markets – what impact for consumers and producers?
    Electricity market design is evolving with the increase in electricity generated from renewable sources. The market system was originally designed for dispatchable fossil fuel electricity generation with high marginal costs rather than renewable electricity generation with nearly zero marginal costs and high upfront capital costs. When short term prices no longer cover long term investment costs, new market design is needed.
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  • Publication
    Integrating European Electricity Markets – what impact for consumers and producers?
    Electricity market design is evolving with the increase in electricity generated from renewable sources. The market system was originally designed for dispatchable fossil fuel electricity generation with high marginal costs rather than renewable electricity generation with nearly zero marginal costs and high upfront capital costs. When short term prices no longer cover long term investment costs, new market design is needed. An alternative is to increase interconnection to facilitate increased trade between markets (Pollitt and Chyong, 2018). Economic theory would suggest that eliminating barriers to trade across a regional market will decrease consumer costs and producer profits in areas that increase imports, while increasing producer profits and consumer costs in areas that increase exports (Dahlke, 2018). Trade through interconnectors can exploit differences in wind and sun conditions across regions and so reduce supply variability; higher shares of renewable electricity raises the value of market integration even further (Newbery et al., 2018). In this context, the EU has been progressively harmonizing national and regional electricity markets, to form a single market that includes more than 500 million people. The Multi-Regional Coupling organized through European power exchanges coordinates the clearing of day-ahead markets and determines day-ahead prices across the countries involved (Politico, 2018). In the 1996, 2003 and 2009 EU electricity directives, the development of integrated wholesale power markets across the continent was encouraged in order to incentivise market-driven investment in generation across Europe. The Internal Energy Market (IEM) in Europe provides for free trade across border and non-discrimination between internal and cross-border transactions. On October 1st 2018, Ireland was one of the final countries to integrate with this market due to the small isolated nature of this synchronous system which required additional precautions to put in place new market arrangements. The Irish electricity market has been a wholesale all-island market (including Northern Ireland, called the SEM) since 2007. The integration of the all-island electricity market with European electricity markets was expected to increase the use of the interconnector with Great Britain which should “deliver increased levels of competition which should help put a downward pressure on prices as well as encouraging greater levels of security of supply and transparency” (EirGrid, 2016). In addition to integration with Europe, other features were included in the new I-SEM market, such as changes to how energy is bought and sold; how generators are remunerated for availability; forward trading arrangements and market liquidity; market power controls; and the systems, policies and procedures that are required to operate the market (EirGrid, 2016). This has led to new balancing, capacity, and intraday markets that did not previously exist in the Irish market. With the integration of the Irish market, the IEM now comprises 20 countries, with 38 interconnectors and a total generating capacity of over 3,000 TW (EirGrid, 2016). The European Target model sets out the common rules and arrangements for market coupling in Europe. It includes a common price coupling algorithm for scheduling day-ahead markets and determining flows between geographic regions. The energy transactions involving sellers and buyers from different bidding zones are centrally collected to maximise the most efficient and effective trades. In theory, unless the network is congested, markets should converge to a single price. When the network is congested, prices diverge. The integration of the Irish electricity market with the IEM provides a natural experiment with which to test economic theory relating to the benefits of interconnection, regional electricity trade, and market rule changes for consumers,producers and markets. While there is an extensive literature on electricity market design and theory, it is rare to find empirical data such as this with which to test the theory. This integration is relatively recent, yet it provides an ideal opportunity to examine in detail several features over the period directly before and after the change. Ireland, as an isolated market. Ireland has been identified as a country at the forefront of market change due to the high share of renewable electricity and its isolated market (Polllitt and Chyong, 2018). It also serves as a good case study, as there are less confounding factors in an analysis of market design, compared with more geographically integrated countries.
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  • Publication
    Integrating European Electricity Markets – what impact for consumers and producers?
    The objective of this paper is to examine the impact on prices and electricity trading of integrating a small market into a larger electricity market. Economic theory would suggest that eliminating barriers to trade across a regional market will decrease consumer costs and producer profits in areas that increase imports, while increasing producer profits and consumer costs in areas that increase exports. Electricity market design is evolving with the increase in electricity generated from renewable sources. Interconnection of electricity systems should facilitate increased trade between markets and provide the flexibility needed to accommodate rising shares of renewable electricity in the system. Trade through interconnectors can exploit differences in wind and sun conditions across regions and so reduce supply variability and hence price volatility. The integration of the European regions electricity markets should therefore increase trade, reduce prices and reduce price volatility. Using a case study of Ireland we examine using econometric methods the integration of the all-island Irish electricity market into the European electricity market. Our preliminary results show that there has been little impact on day ahead prices so far but that electricity trading is operating more efficiently since the integration to the new market.
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  • Publication
    Transition to a Capacity Auction: a Case Study of Ireland
    (International Association of Energy Economics, 2019-06) ;
    Modern electricity markets are characterized by increasing shares of intermittent production which has almost zero marginal costs. The effect of introducing large amounts of cheap power into the system is known as the merit order effect – a shift of a supply curve to the right which delivers lower equilibrium prices. The lower prices and the fact that fossil-fuel generators are used less often exacerbate adequacy problems – there is a threat that not enough generating capacity will be available in the system since generators´ revenues are low and investment needs are not met. This and the fact that energy markets are often capped in order to prevent market power leads to the so called “missing money problem” (Teirila and Ritz, 2018, Bublitz et al., 2019). One possible remedy is to supplement the energy only markets with capacity markets (Newbery, 2016; Cramton et al, 2013; Joskow, 2007). Recently the electricity market on the island of Ireland has been completely restructured, a change that affected also the capacity mechanism, transforming it from an administrative decision-based to a market-based mechanism, an auction. The move however has not been a smooth one, with a supply of Dublin put at risk as one of the main suppliers in the area wanted to withdraw from the market as a result of not being able to successfully secure the operation of its two units. Since Irish electricity demand is forecast to grow by between 15% and 47% over the next ten years, with over a quarter of all electricity consumed by data centres, many of which will be in the Dublin region (EirGrid, 2018a), the threat of losing one of the suppliers become even more serious. In this case study we show how even with considerable analysis and preparation, the introduction of an auction system is not without risk.
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