Impact of Large-Scale integration of Res in electric power systems. Exploration of the future European electricity market design
Resumen
Until recently the European electricity system has been operating as a set of isolated national
markets with divergent regulatory norms. Today, the day-ahead markets between South-
Western Europe and North-Western Europe are fully coupled, enabling the trading of electricity
all the way from Portugal to Finland. Moreover, policy-makers in the power sector are currently
preparing the design of what it will be called the Internal Energy Market. Europe's power sector
aims for an integrated, more competitive, secure and sustainable power system. Meanwhile,
ambitious renewable targets aim for a decarbonization of the electricity sector by 2050. This
will lead to a large deployment of renewable technologies into the system, with almost 50% of
them being the most intermittent, uncertain and unevenly distributed sources in the continent,
wind and solar.
The introduction of the projected large amounts of intermittent sources will impact both the
functioning of the electricity markets and the operation of the transmission grids. Cross-border
congestion profiles are expected to suffer changes, transmission constraints will appear and an
effective congestion management approach will be needed within the framework of the market's
redesign.
Currently, the congestion management mechanism in place in many Member States is based on
a redispatch phase after market clearance, which results in inefficiencies and additional
rebalancing costs. This congestion management approach falls within the zonal market design.
A consistent integration of electricity markets across Europe enabling the access of large
capacities of renewable generation would have the potential to maximize overall welfare to all
agents. Generators would enter a more competitive market with a lower risk, consumers would
benefit from lower electricity prices and transmission system operators would benefit from
reduced operation costs of balancing and reserve.
Locational marginal pricing, also known as nodal market design, would be able to provide an
integrated approach of national and international congestion management, a joint allocation of
international transmission rights, the integration of congestion management with day-ahead,
intraday and balancing markets and finally a transparent approach to facilitate secure and
effective cooperation and information exchange among European system operators. However, a
committed high-level support on a European level would be required for its further
implementation.
The objective of this thesis is to gain a better understanding of the European power market in
presence of large amounts of renewable energies and under different power market designs, and
find out by how much can the market design and its features affect the provision of costefficient
electricity, this is the system's variable generation costs of electricity.
In order to study the influence of the power market design in the integration of large amounts of
renewable energies, an optimization model is used. The model solves a weekly unit commitment problem and the transmission constrained economic dispatch for the day-ahead
market of a conceptual network of Europe and from a centralized decision making point of
view. The model uses a mixed-integer linear programming (MILP) formulation of the unit
commitment and minimizes total variable generation costs of the system. The two market
designs studied, nodal market and zonal market, are modeled according to how congestion is
managed in each case. The aim is to analyze the impact of the power market design on the power system's variables:
total variable generation costs, RES curtailment, energy production by technology, non-served
energy and hourly electricity prices while subjected to several scenarios of increasing degree of
RES integration. For this, different degrees of future RES scenarios based on ENTSO-E market
studies are used.
The research shows that in a high renewable scenario the total variable generation costs of the
power system when it operates under a zonal power market are around 0,32% higher than under
a nodal market. These potential savings under a nodal market could even be larger especially if
the large expected projections of renewable sources of generation finally materialize and
provided that the required network capacities are delivered effectively on time. Moreover, the degree of curtailment in both nodal and zonal markets rise notably in a high
renewable scenario compared to the current situation, up to a weekly curtailment of 7,83% and
8,01%, respectively. Such notable amounts of curtailment could be due to the insufficient
development of the transmission network assumed which leads to the incapability of supplying
cheap renewable energy across wide regions and instead having to commit or reschedule local
and more expensive technologies.
On the other hand, costs of unserved energy represent 2,95% and 3,08% of the total system's
variable generation costs in the nodal and zonal market, respectively. It is again highlighted the
importance of a timely delivery of the network infrastructure investments to gradually integrate
the large deployment of renewables in the system. Overall, a nodal market in Europe could have the potential of improving efficiency in the
system by reducing variable generation costs by 0,32% compared to a zonal market. Benefits
could increase even more if an adequate network expansion plan that takes into account the
growth of renewable energies would deliver its investments on a timely manner.
Trabajo Fin de Máster
Impact of Large-Scale integration of Res in electric power systems. Exploration of the future European electricity market designTitulación / Programa
Master in the Electric Power IndustryMaterias/ UNESCO
33 Ciencias tecnológicas3306 Ingeniería y tecnología eléctrica
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