Abstract
This paper proposes a model to compute nodal prices in oligopolistic markets. The model generalizes a previous model aimed at solving the single-bus problem by applying an optimization procedure. Both models can be classified as conjectured supply function models. The conjectured supply functions are assumed to be linear with constant slopes. The conjectured price responses (price sensitivity as seen for each generating unit), however, are assumed to be dependent on the system line's status (congested or not congested). The consideration of such a dependence is one of the main contributions of this paper. Market equilibrium is defined in this framework. A procedure based on solving an optimization problem is proposed. It only requires convexity of cost functions. Existence of equilibrium, however, is not guaranteed in this multi-nodal situation and an iterative search is required to find it if it exists. A two-area multi-period case study is analysed. The model reaches equilibrium for some cases, mainly depending on the number of periods considered and on the value of conjectured supply function slopes. Some oscillation patterns are observed that can be interpreted as quasi-equilibria. This methodology can be applied to the study of the future Iberian electricity market.
Similar content being viewed by others
References
Barquin J and Vazquez M (2003). Cournot equilibrium computation on electricity networks. In: Voropai N.I. and Handschin E.J. (eds). Proceedings of the 2nd International Conference on Liberalization and Modernization of Power Systems: Congestion Management Problems. Energy Systems Institute: Irkustsk, Russia, pp. 166–172.
Barquín J, Centeno E and Reneses J (2004). Medium-term generation programming in competitive environments: A new optimization approach for market equilibrium computing. IEE Proc Gen Transm Distrib 151: 119–126.
Barquín J, Centeno E and Reneses J (2005). Stochastic market equilibrium model for generation planning. Probability Eng Inform Sci 19: 533–546.
Boucher J and Smeers Y (2002). Towards a common European electricity market: Paths in the right direction still far from an effective design. J Network Ind 3: 375–424.
Bunn DW (2003). Modelling Prices in Competitive Electricity Market. Wiley finance series. Wiley: Chichester, England, pp 58–65.
Centeno E, Barquín J, de la Fuente JI, Muñoz A, Ventosa M, García-González J, Mateo A and Martín-Calmarza A (2003). Competitors' response representation for market simulation in the Spanish daily market. Modelling Prices in Competitive Electricity Market. Wiley finance series, Chapter 1, Wiley: Chichester, West Sussex, England.
Centeno E, Reneses J and Barquín J (2007). Strategic analysis of electricity markets under uncertainty: A conjectured-price-response approach. IEEE Trans Power Systems 22: 423–432.
Daxhelet O and Smeers Y (2001). Variational inequality models of restructured electric systems. In: Ferris M.C., Mangasarian O.L. and Pang J.-S. (eds). Complementarity: Applications, Algorithms and Extensions Vol. 50. Kluwer Academic, Applied optimization: Dordrecht, The Netherlands, pp. 85–120.
Day CJ, Hobbs BF and Pang JS (2002). Oligopolistic competition in power networks: A conjectured supply function approach. IEEE Trans Power Systems 17: 597–607.
Ehrenmann A (2004). Manifolds of multi-leader Cournot equilibria. Opns Res Lett 32: 121–125.
Figuières CA, Jean-Marie N, Quérou N and Tidball M (2004). Theory of Conjectural Variations. Series on mathematical economics and game theory Vol. 2. World Scientific: River Edge, NJ, USA.
Hobbs BF (2001). Linear complementarity models of Nash–Cournot competition in bilateral and POOLCO power markets. IEEE Trans Power Systems 16: 194–202.
Hobbs BF and Helman U (2003). Complementarity-based equilibrium modeling for electric power markets. In: Bunn, D (ed). Modeling Prices in Competitive Electricity Markets, Wiley finance series, Chapter 3. Wiley: Chichester, England.
Neuhoff K (2003). Combining energy and transmission markets mitigates market power. CMI Working Paper 17, Department of Applied Economics, Cambridge University.
Neuhoff K, Barquin J, Boots MG, Ehrenmann A, Hobbs BF, Rijkers FAM and Vázquez M (2005). Network-constrained Cournot models of liberalized electricity markets: The devil is in the details. Energy Econ 27: 495–525.
Ramos A, Ventosa M and Rivier M (1999). Modeling competition in electric energy markets by equilibrium constraints. Utilities Policy 7: 233–242.
Red Eléctrica de España (2006). El sistema eléctrico español, Informe 2005, available at http://www.ree.es/sistema_electrico/pdf/infosis/Inf_Sis_Elec_REE_2005_SistemaPeninsular05.pdf as of March, 2006 (in Spanish).
Reneses J, Centeno E, and Barquín J (2001). Computation and decomposition of marginal costs for a GENCO in a constrained competitive Cournot equilibrium. Proceedings of the IEEE Power Tech Conference, Vol. 1, Paper POM3-204. Porto, Portugal.
Reneses J (2004). Análisis de la Operación de los Mercados de Generación de Energía Eléctrica a Medio Plazo. PhD Thesis, Universidad Pontificia Comillas, Madrid.
Rivier M, Ventosa M and Ramos A (2001). A generation operation planning model in deregulated electricity markets based on the complementary problem. In: Ferris M.C., Mangasarian O.L. and Pang J.-S. (eds). Complementarity: Applications, Algorithms and Extensions. Kluwer Academic Publishers: The Netherlands, pp. 273–296.
Rockafellar RT (1970). Convex Analysis. Princeton Landmarks in Mathematics and Physics. Princeton University Press: Princeton, NJ, USA.
Schweppe FC, Caramanis MC, Tabors RE and Bohn RE (1988). Spot Pricing of Electricity. Kluwer: Norwell, MA.
Song Y, Ni Y, Wen F, Hou Z and Wu FF (2003). Conjectural variation based bidding strategy in spot markets: Fundamentals and comparison with classical game theoretical bidding strategies. Electric Power Systems Res 67: 45–61.
Wood AJ and Wollenberg BF (1996). Power Generation, Operation, and Control, 2nd edn. Wiley: New York, USA.
Author information
Authors and Affiliations
Corresponding author
Additional information
2Current address: Departmento de Estadística e Investigación Operativa I, Facultad de Ciencias Matemáticas, Universidad Complutense de Madrid, Plaza de Ciencias, 3, 28040 Madrid, Spain.
Appendices
Appendix A
This appendix is devoted to prove some numerical results used in Section 2, which can be easily generalized to obtain the results for several areas of Section 3.
Lemma
-
Let C(P) be a convex function and θ, α⩾0. So, the following expressions where ΔC P (ΔP) denotes C(P+ΔP)−C(P), are equivalent:
-
a)
πΔP⩽θΔP+ΔC P (ΔP), ∀ΔP
-
b)
πΔP⩽θΔP+ΔC P (ΔP)+α(ΔP)2, ∀ΔP
-
a)
Proof
-
(a) ↠ (b) is obvious, so we only need to prove (b) ↠ (a), that is, πΔP⩽θΔP+ΔC P (ΔP)+α(ΔP)2, ∀ΔP implies πΔP⩽θΔP+ΔC P (ΔP), ∀ΔP
First, because C(P) is a convex function of P, ΔC P (ΔP) is a convex function of ΔP. So, ΔC P (ΔP)+θΔP+α(ΔP)2 is also a convex function. Expression (b) implies that π is a subgradient of this function. Therefore, π is the addition of subgradients of every added term, evaluated at ΔP=0, that is
This means that π is a subgradient of convex function θΔP+ΔC P (ΔP), which implies (a), and the proof is finished. □
Proposition
-
Let C(P) be a convex function and θ⩾0. So, the following three expressions where ΔC P (ΔP) denotes C(P+ΔP)−C(P), are equivalent:
-
a)
πΔP⩽θΔP+ΔC P (ΔP), ∀ΔP
-
b)
πΔP⩽θΔP+ΔC P (ΔP)+θ(ΔP)2, ∀ΔP
-
c)
πΔP⩽ΔC P (ΔP)+Δ(½θP 2) = Δ(C(P)+½θP 2), ∀ΔP
-
a)
Proof
-
Applying the previous lemma is immediate because both expressions differ from the first one in terms ½θ(ΔP)2 and θ(ΔP)2. □
Appendix B
This appendix contains a result needed in Section 3 that proves the equivalence between the equilibrium constraints and the optimization problem and which is not included in the main text to make the reading easier.
Theorem
-
P(S *) and V(S *) are equivalent.
Proof
-
To prove that every solution of V(S *) is a minimum of problem P(S *), let us add the first set of inequalities in V(S *), that is
On the other hand, from the demand constraints
So
from the absence of transport arbitrage condition, and therefore
which proves that the solution of V(S *) is actually an optimal solution of P(S *).
To prove that every solution of P(S *) fulfils V(S *) let us consider the Lagrangian:
As P(S *) is a convex problem, in the optimum L has a saddle point, which is a minimum with respect to each generated power, that is
By considering situations where a generating company only changes its output, the first set of inequalities in V(S *) is obtained. In contrast, it must be as well to be a minimum with respect to any feasible increment, that is
which is nothing else but a non-arbitrage condition. □
Rights and permissions
About this article
Cite this article
Barquín, J., Vitoriano, B., Centeno, E. et al. An optimization-based conjectured supply function equilibrium model for network constrained electricity markets. J Oper Res Soc 60, 1719–1729 (2009). https://doi.org/10.1057/jors.2008.118
Received:
Accepted:
Published:
Issue Date:
DOI: https://doi.org/10.1057/jors.2008.118