Abstract
The deregulation of electricity markets in Europe has deeply changed the organization of this sector. Vertically integrated generating companies have been unbundled to create competition and to increase the competitiveness of electricity markets. Directive 96/92/EC was issued by the European Commission to liberalize electricity markets and to pave the way for the creation of the Internal Electricity Market. In particular, this Directive aimed at promoting the competition in the activities of electricity generation and wholesale through the creation of a “marketplace” and the maximization of transparency and efficiency. Competition in European day-ahead electricity markets has been established through auction markets where electricity producers and consumers offer/bid prices and volumes. This paper suggests a dynamic equilibrium model for a system of auction markets linked by transmission lines and subject to energy balance and transmission constraints, such as those characterizing restructured electricity markets. This model is treated as a system of variational inequalities with arbitrary monotone mappings. An inexact splitting type method is proposed to find its solution. Numerical experiments are conducted on the Italian day-ahead electricity market.
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Notes
See Appendix A for the definition.
See Appendix A for the definition.
Note that implicit auction is at the basis of “market splitting” and “market coupling”. For more details see http://www.moffatt-associates.com/energy_services/forecasting_market_trends/ energy_viewpoints/documents/12/market_coupling_key_to_eu_power_market_integration.pdf http://www.moffatt-associates.com/energy_services/forecasting_market_trends/ energy_viewpoints/documents/12/market_coupling_key_to_eu_power_market_integration.pdf and http://www.acer.europa.eu/Electricity/Regional_initiatives/Cross_Regional_Roadmaps/Pages/1.-Market-Coupling.aspx http://www.acer.europa.eu/Electricity/Regional_initiatives/Cross_Regional_Roadmaps/Pages/1.-Market-Coupling.aspx. Accessed 6 December 2014. In this work, this author was supported by the RFBR grant, project No. 16-01-00109a.
The parameter \(\beta ^{\prime }_{s,t}\) is equal to \(+\infty \) when the production process in not subject to any technical constraint.
The case where the lower bound \(\alpha _{s,t}^{\prime }\) is set equal to zero and auction price p i,t is lower than traders’ offer price g s,t (x (i),t ,y (i),t ) represents a situation where traders can either decide to not produce anything or are excluded from the auction mechanism.
The case where the lower bound \(\alpha _{s,t}^{\prime \prime }\) is set equal to zero and auction price p i,t is higher than buyers’ bid price h q,t (x (i),t ,y (i),t ) corresponds to the situation where buyers can either decide to not purchase anything or are not involved in the auction mechanism.
Theorem 3.4 of Konnov ( 2008) states that the mapping p i ↦U i (p i ) is monotone and that U i (p i ) is the subdifferential of some convex function \(\psi _{i}: \mathbb {R} \to \mathbb {R}\) at p i .
Note that a more general notation for transportation cost mapping c i j,t would have been c i j,t = c i j,t (f,p) rather than the adopted c i j,t = c i j,t (f). However, complementarity condition (4) explicitly states the dependence of transportation costs mapping c i j,t on the price difference between markets i and j and thus only the dependence on f remains.
The reasoning applied to transmission cost mapping c i j,t (f) also holds for the storage cost mapping r i,t (v). A more general notation of this mapping would have been r i,t = r i,t (v,p) rather than the adopted r i,t = r i,t (v). However, complementarity condition (5) explicitly states the dependence of storage cost mapping v i,t on the price difference between time intervals (t−1) and t and thus only the dependence on v remains.
In a more general framework u i,t should be expressed as follows: u i,t (f,v,p). However, complementarity condition (6) explicitly states the dependence of u i,t on flows f and storage v. For this reason, we simply write u i,t (p).
More details are available at https://www.epexspot.com/en/market-coupling/pcr. Accessed 6 December 2014.
In addition, there exist some bounds on the ramping rate between two successive time intervals, on the minimal downtime between plant shut-down and start-up, and on the minimal running time between start-up and shut-down phases.
In the current organization of the European electricity market, based on Market Coupling, the real representation of the network based on Kirchhoff’s laws is only considered by TSO when operating the ancillary service market.
Some of the geographical zones group together several Italian regions. In particular, North includes Aosta Valley, Piedmont, Liguria, Lombardy, Trentino Alto Adige, Veneto, Friuli Venezia Giulia and Emilia Romagna; Central North assembles together Tuscany, Umbria and Marche; Central South gathers Lazio, Abruzzo and Campania; South which accounts for Molise, Apulia, Basilicata and Calabria.
Data are available at the following link http://www.terna.it/default/Home/SISTEMA_{E} LETTRICO/mercato_elettrico/Procedura_valutazione_limiti_e_limiti_transito.aspx. Accessed 6 December 2014.
Data are available at https://www.entsoe.eu/publications/market-reports/ntc-values/ntc-matrix/. Accessed 6 December 2014.
See ENTSO-E Overview of transmission tariffs in Europe: Synthesis 2013 available at https://www.entsoe.eu/publications/market-reports/Documents/SYNTHESIS_2013_UPDATED_140703.pdf https://www.entsoe.eu/publications/market-reports/Documents/SYNTHESIS_2013_UPDATED_140703.pdf. Accessed 6 December 2014.
These are represented by Enel, Eni, and Edison which globally cover the 42 % of the Italian electricity production (see Annual Report 2014 of the Italian Authority of energy, gas, and hydro system http://www.autorita.energia.it/allegati/relaz_ann/14/RAVolumeI_2014.pdf http://www.autorita.energia.it/allegati/relaz_ann/14/RAVolumeI_2014.pdf. Accessed 6 December 2014.
See ENTSO-E website https://www.entsoe.eu/data/data-portal/production/ and Terna http://www.terna.it/it-it/sistemaelettrico/statisticheeprevisioni/datistatistici.aspx. Accessed 6 December 2014.
Available capacity values result from the product between the installed capacity of the different technologies and the respective availability factors. When considering wind power plant we compute adequate availability factors depending on zone i. These availability factors are obtained by dividing the annual wind energy production in zone i by the respective annual installed wind capacity. We do the same for all other renewable energy source based plants, i.e. hydroelectric and photovoltaic units. In this way, we implicitly account for the fact that wind and other renewables based plants are not dispatchable technologies. We took as reference year 2012 that is used to calibrate all other data used in the simulations. Note that capacity values reported in Table 6 are obtained by making the sum over technology of data in Table 11. Installed capacity data per technology are taken from companies’ annual reports, from Eurostat http://appsso.eurostat.ec.europa.eu/nui/show.do?dataset=nrg_113a&lang=en, from ENTSO-E https://www.entsoe.eu/data/data-portal/miscellaneous/, and from Terna http://www.terna.it/default/Home/SISTEMA_ELETTRICO/statistiche/dati_statistici.aspx http://www.terna.it/default/Home/SISTEMA_ELETTRICO/statistiche/dati_statistici.aspx. Accessed 6 December 2014.
CO 2 allowance prices are available at http://www.eex.com/en/market-data/emission-allowances/ auction-market/european-emission-allowances-auction/european-emission-allowances-auction-download http://www.eex.com/en/market-data/emission-allowances/auction-market/ european-emission-allowances-auction/european-emission-allowances-auction-download. Accessed 6 December 2014.
See http://ec.europa.eu/clima/policies/ets/linking/index_en.htm. Accessed 6 December 2014.
Consumers could have been subdivided into different groups such as households, small industries, energy-intensive industries, and services. Unfortunately we do not dispose of information about consumption level of each of these consumer groups in the different market zones and therefore we consider only one representative consumer per zone.
See Gestore Mercato Elettrico (GME) website at http://www.mercatoelettrico.org/It/Download/DatiStorici.aspx. Accessed 6 December 2014.
Demand data are taken from GME http://www.mercatoelettrico.org/It/Download/DatiStorici.aspxand from ENTSO-E https://www.entsoe.eu/data/data-portal/miscellaneous/. Accessed 6 December 2014.
Data are provided by GME http://www.mercatoelettrico.org/It/Download/DatiStorici.aspx. Accessed 6 December 2014.
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Appendices
Appendix
1.1 A Definitions
In this Appendix, we explain the meaning of some abbreviations used throughout the paper.
1.2 A.1 Power Exchange (PX)
As indicated at page 15 of Directorate-General for Directorate-General for Energy and Transport ( 2008), “Electricity Power Exchanges (PXs) are voluntary trading platforms pro- posing standardized instruments and clearing services to their members. The range of the products traded on a power exchange varies from a single hour delivery of electricity on a predefined high voltage grid for the next day (or even the intra day) to an elaborate contract covering periods stretching to a couple of years. PX are organised in two interrelated parts - the physical and the forward segments. The physical segment covers the trade with contracts that are closest to maturity. The forward segment of the power exchange provides the platform for trading derivative contracts”
1.3 A.2 Transmission System Operator (TSO)
As indicated by the UCTE Operation Handbook-Glossary (2014), “a Transmission System Operator is a company that is responsible for operating, maintaining and developing the transmission system for a control area and its interconnections”. A control area usually coincides “with the territory of a company, a country or a geographical area, physically demarcated by the position of points for measurement of the interchanged power and energy to the remaining interconnected network, operated by a single TSO, with physical loads and controllable generation units connected within the control area (See pages G-4 and G-14).
B Notation
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\(t=\{1, \dots , T\}\): Set of time subintervals;
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\(i=\{1, \dots , N\}\): Set of auction markets (zones). In each zone, there are traders and buyers that participate to the auction mechanism. We define with S i and Q i the set of traders and buyers that respectively offer and bid in market i;
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\(\alpha _{s,t}^{\prime }\): Lower bound imposed on the (electricity) offer submitted by trader (power producer) s at time t;
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\(\beta _{s,t}^{\prime }\): Upper bound imposed on the (electricity) offer submitted by trader (power producer) s at time t;
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\(\alpha _{q,t}^{\prime \prime }\): Lower bound imposed on the (electricity) bid submitted by buyer (power consumer) q at time t;
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\(\beta _{q,t}^{\prime \prime }\): Upper bound imposed on the (electricity) bid submitted by buyer (power consumer) q at time t;
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\(a_{s,t}^{g}\), \(b_{s,t}^{g}\): Intercept and slope of the offer price function of power producer s participating to the auction organized in zone i at time t;
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\(a_{i,t}^{h}\), \(b_{i,t}^{h}\): Intercept and slope of the bid price function of consumers participating to the auction organized in zone i at time t;
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x s,t : Offer submitted to the auction by trader s at time t;
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y q,t : Bid submitted to the auction by buyer q at time t;
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u i,t : Excess of (electricity) supply (u i,t ≥0) or excess of (electricity) demand (u i,t ≤0) in zone i at time t;
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f i j,t : Electricity flow from zone i to zone j at time t;
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v i,t : Electricity stored in zone i at time t;
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p i,t : Electricity price resulting from the auction clearing in zone i at time t.
C Additional Data
In this section, we report additional data that have been used in our numerical experiments.
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Allevi, E., Gnudi, A., Konnov, I.V. et al. Dynamic Spatial Auction Market Models with General Cost Mappings. Netw Spat Econ 17, 367–403 (2017). https://doi.org/10.1007/s11067-016-9330-1
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DOI: https://doi.org/10.1007/s11067-016-9330-1