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Hesamzadeh, Mohammad Reza
Publications (10 of 14) Show all publications
Yuan, Z. & Hesamzadeh, M. R. (2018). A Distributed Economic Dispatch Mechanism to Implement Distribution Locational Marginal Pricing. In: 2018 POWER SYSTEMS COMPUTATION CONFERENCE (PSCC): . Paper presented at 2018 POWER SYSTEMS COMPUTATION CONFERENCE (PSCC). IEEE
Open this publication in new window or tab >>A Distributed Economic Dispatch Mechanism to Implement Distribution Locational Marginal Pricing
2018 (English)In: 2018 POWER SYSTEMS COMPUTATION CONFERENCE (PSCC), IEEE , 2018Conference paper, Published paper (Refereed)
Abstract [en]

We address the challenges of power flow computation and network operator coordination to implement distribution locational marginal pricing (DLMP) in this paper. Compared with other dynamic pricing schemes, DLMP can give clearer economic signals regarding distributed energy resources (DERs) investment, demand side response, congestion management and network reinforcement. Without neglecting the power loss of distribution network, the second-order cone AC optimal power flow (SOPF) model is used here to calculate DLMP. A distributed economic dispatch mechanism based on the modified Benders decomposition and distributed generation cost (DGC) is proposed to reduce the dispatch complexity in facing high penetration of DERs. The key contribution is that we take the tie-line power flow as the complicating variable to formulate the modified Benders decomposition algorithm. The concept of DGC is proposed to reallocate the global dispatch cost to economically incentivize the regional network operators for coordination. The distributed economic dispatch mechanism is implemented in GAMS grid computing platform. Numerical results show that SOPF can give accurate power flow and DLMP results. The fast convergence of the proposed distributed dispatch is guaranteed by the convexity of the SOPF model and efficient grid computing technique.

Place, publisher, year, edition, pages
IEEE, 2018
Keywords
Terms Distribution locational marginal pricing, optimal power flow, Benders decomposition, distributed economic dispatch, GAMS grid computing
National Category
Other Electrical Engineering, Electronic Engineering, Information Engineering
Identifiers
urn:nbn:se:kth:diva-238166 (URN)10.23919/PSCC.2018.8442804 (DOI)000447282400117 ()2-s2.0-85054011288 (Scopus ID)
Conference
2018 POWER SYSTEMS COMPUTATION CONFERENCE (PSCC)
Note

QC 20181107

Available from: 2018-11-07 Created: 2018-11-07 Last updated: 2018-11-07Bibliographically approved
Hesamzadeh, M. R., Rosellón, J., Gabriel, S. A. & Vogelsang, I. (2018). A simple regulatory incentive mechanism applied to electricity transmission pricing and investment. Energy Economics, 75, 423-439
Open this publication in new window or tab >>A simple regulatory incentive mechanism applied to electricity transmission pricing and investment
2018 (English)In: Energy Economics, ISSN 0140-9883, E-ISSN 1873-6181, Vol. 75, p. 423-439Article in journal (Refereed) Published
Abstract [en]

The informationally simple approach to incentive regulation applies mechanisms that translate the regulator's objective function into the firm's profit-maximizing objective. These mechanisms come in two forms, one based on subsidies/taxes, the other based on constraints/price caps. In spite of a number of improvements and a good empirical track record simple approaches so far remain imperfect. The current paper comes up with a new proposal, called H-R-G-V, which blends the two traditions and is shown in simulations to apply well to electricity transmission pricing and investment. In particular, it induces immediately optimal pricing/investment but is not based on subsidies. In the transmission application, the H-R-G-V approach is based on a bilevel optimization with the transmission company (Transco) at the top and the independent system operator (ISO) at the bottom level. We show that H-R-G-V, while not perfect, marks an improvement over the other simple mechanisms and a convergence of the two traditions. We suggest ways to deal with remaining practical issues of demand and cost functions changing over time. 

Place, publisher, year, edition, pages
Elsevier B.V., 2018
Keywords
Bilevel program, Incentive regulation, Transmission investment, Cost functions, Costs, Electric utilities, Investments, Bi-level optimization, Bilevel programs, Demand and cost functions, Electricity transmission, Incentive regulations, Independent system operators, Transmission company (TRANSCO), Transmission investments, Economics, electricity supply, incentive, investment, optimization, pricing policy, regulatory approach
National Category
Economics and Business
Identifiers
urn:nbn:se:kth:diva-236731 (URN)10.1016/j.eneco.2018.08.033 (DOI)2-s2.0-85053842506 (Scopus ID)
Note

Export Date: 22 October 2018; Article; CODEN: EECOD; Correspondence Address: Hesamzadeh, M.R.; Electricity Market Research Group (EMReG), KTH Royal Institute of TechnologySweden; email: mrhesamzadeh@ee.kth.se; Funding details: 232743; Funding text: The authors would like to thank Dina Khastieva for her help in numerical results of this paper. Juan Rosellón acknowledges support from a Conacyt-Sener-FSE grant no. 232743 . QC 20181023

Available from: 2018-10-23 Created: 2018-10-23 Last updated: 2018-10-23Bibliographically approved
Moiseeva, E. & Hesamzadeh, M. R. (2018). Bayesian and Robust Nash Equilibria in Hydrodominated Systems Under Uncertainty. IEEE Transactions on Sustainable Energy, 9(2), 818-830
Open this publication in new window or tab >>Bayesian and Robust Nash Equilibria in Hydrodominated Systems Under Uncertainty
2018 (English)In: IEEE Transactions on Sustainable Energy, ISSN 1949-3029, E-ISSN 1949-3037, Vol. 9, no 2, p. 818-830Article in journal (Refereed) Published
Abstract [en]

In this paper, we model strategic interaction of multiple producers in hydrodominated power systems under uncertainty as an equilibrium problem with equilibrium constraints (EPEC), reformulated as a stochastic mixed-integer linear program with disjunctive constraints. We model strategic hydropower producers who can affect the market price by submitting strategic bids in quantity, price, and ramp rate. The bids are submitted to the system operator who minimizes the dispatch cost. We take into account the hydrospecific constraints and uncertainty in the system. Solving the problem results in finding Nash equilibria. We discuss two types of Nash equilibria under uncertainty: Bayesian and robust Nash equilibria. Large EPEC instances can be solved using a decomposition method-Modified Benders Decomposition Approach. This method eliminates the problem of tuning the disjunctive parameter and reduces the memory requirements, resulting in improved computation time.

Place, publisher, year, edition, pages
IEEE-INST ELECTRICAL ELECTRONICS ENGINEERS INC, 2018
Keywords
EPEC, stochastic programming, disjunctive constraint, modified benders decomposition approach
National Category
Control Engineering
Identifiers
urn:nbn:se:kth:diva-226200 (URN)10.1109/TSTE.2017.2762086 (DOI)000428687400029 ()2-s2.0-85031788334 (Scopus ID)
Note

QC 20180518

Available from: 2018-05-18 Created: 2018-05-18 Last updated: 2018-05-18Bibliographically approved
Grigoryeva, A., Hesamzadeh, M. R. & Tangerås, T. (2018). Energy system transition in the Nordic market: Challenges for transmission regulation and governance. Economics of Energy & Environmental Policy, 7(1), 127-146
Open this publication in new window or tab >>Energy system transition in the Nordic market: Challenges for transmission regulation and governance
2018 (English)In: Economics of Energy & Environmental Policy, ISSN 2160-5882, E-ISSN 2160-5890, Vol. 7, no 1, p. 127-146Article in journal (Refereed) Published
Abstract [en]

The energy system in the Nordic countries faces changes driven by increasing integration with the rest of Europe and changes to the generation mix. These developments pose challenges with respect to future network development and operation. We focus on three major aspects: market integration; generation and network adequacy; the need for more flexibility and frequency control. We describe factors behind these problems and present possible solutions within the Nordic context. One conclusion is that supranational cooperation should be further improved.

Place, publisher, year, edition, pages
International Association for Energy Economics, 2018
Keywords
Energy policy, Market integration, Transmission regulation
National Category
Energy Systems
Identifiers
urn:nbn:se:kth:diva-238405 (URN)10.5547/2160-5890.7.1.agri (DOI)2-s2.0-85046160702 (Scopus ID)
Note

QC 20181031

Available from: 2018-10-31 Created: 2018-10-31 Last updated: 2018-10-31Bibliographically approved
Tohidi, Y., Hesamzadeh, M. R. & Regairaz, F. (2018). Modified Benders Decomposition for Solving Transmission Investment Game With Risk Measure. IEEE Transactions on Power Systems, 33(2), 1936-1947
Open this publication in new window or tab >>Modified Benders Decomposition for Solving Transmission Investment Game With Risk Measure
2018 (English)In: IEEE Transactions on Power Systems, ISSN 0885-8950, E-ISSN 1558-0679, Vol. 33, no 2, p. 1936-1947Article in journal (Refereed) Published
Abstract [en]

This paper proposes a mathematical model for transmission investment game where there are several transmission planners (TPs). The model is developed assuming a simultaneous-move game between TPs. Each TP maximizes the total surplus (producers', consumers', and transmission surplus) minus the investment cost of its region given the investment decisions of rival TPs. The transmission investment risk is also considered using the probability-of-shortfall measure. We assume one market operator who dispatches the generators in all TP's regions. The risk-constrained Nash equilibria model is formulated as amixed-integer linear program (MILP). To solve the proposed MILP, a solution algorithm is proposed that combines the standard branch-and bound algorithm (BB) with a proposed modified benders decomposition algorithm (MBD). The proposed BB-MBD algorithm is also parallelized to improve the computation performance. To improve the coordination between TPs, a supporting budget mechanism is also mathematically modeled in the MILP. The numerical results are carried out using the 9-bus 3-area and the IEEE Three Area RTS-96 networks. The computational performance of proposed BB-MBD is compared with standard BB algorithm.

Place, publisher, year, edition, pages
IEEE-INST ELECTRICAL ELECTRONICS ENGINEERS INC, 2018
Keywords
Benders decomposition, risk assessment, transmission investment game
National Category
Electrical Engineering, Electronic Engineering, Information Engineering
Identifiers
urn:nbn:se:kth:diva-224016 (URN)10.1109/TPWRS.2017.2743823 (DOI)000425530300069 ()2-s2.0-85028547583 (Scopus ID)
Note

QC 20180323

Available from: 2018-03-23 Created: 2018-03-23 Last updated: 2018-03-23Bibliographically approved
Sarfati, M., Hesamzadeh, M. R., Biggar, D. R. & Baldick, R. (2018). Probabilistic pricing of ramp service in power systems with wind and solar generation. Renewable & sustainable energy reviews, 90, 851-862
Open this publication in new window or tab >>Probabilistic pricing of ramp service in power systems with wind and solar generation
2018 (English)In: Renewable & sustainable energy reviews, ISSN 1364-0321, E-ISSN 1879-0690, Vol. 90, p. 851-862Article in journal (Refereed) Published
Abstract [en]

This paper proposes a probabilistic pricing which achieves efficient operation of and investment in ramp-service providers in power systems with a large amount of wind or solar generation. The proposed pricing differs from the existing literature in that it focuses exclusively on the efficient dispatch of electrical energy with no exogenous consideration of the need for reserves or balancing services. The proposed optimal dispatch task determines both the efficient level of any preventive actions taken before a contingency event occurs and the efficient response of the power system - i.e., corrective actions - once an event occurs. We show analytically that the efficient dispatch outcome can be achieved in a decentralized market mechanism provided the market participants are profit-maximizers and price-takers. We show how the total economic benefit of an investment can be decomposed into two components (a) the normal dispatch cost benefit and (b) the economic value of the investment in contributing ramp service to the power system. In order to study different aspects of the probabilistic pricing, the IEEE 30-node example system is deliberately modified. The results show the efficiency of the proposed pricing and the use of the investment model to assess the economic value of ramp-service providers.

Place, publisher, year, edition, pages
Elsevier, 2018
Keywords
Investment in ramp-service providers, Power system flexibility, Probabilistic pricing
National Category
Energy Systems
Identifiers
urn:nbn:se:kth:diva-227533 (URN)10.1016/j.rser.2018.03.037 (DOI)000434917700057 ()2-s2.0-85045417853 (Scopus ID)
Note

QC 20180515

Available from: 2018-05-15 Created: 2018-05-15 Last updated: 2018-07-02Bibliographically approved
Yuan, Z. & Hesamzadeh, M. R. (2018). Second-Order Cone AC Optimal Power Flow:Convex Relaxations and Feasible Solutions.
Open this publication in new window or tab >>Second-Order Cone AC Optimal Power Flow:Convex Relaxations and Feasible Solutions
2018 (English)Manuscript (preprint) (Other academic)
National Category
Electrical Engineering, Electronic Engineering, Information Engineering
Research subject
Electrical Engineering
Identifiers
urn:nbn:se:kth:diva-227298 (URN)
Note

QC 20180523

Available from: 2018-05-07 Created: 2018-05-07 Last updated: 2018-05-23Bibliographically approved
Moiseeva, E. & Hesamzadeh, M. R. (2018). Strategic Bidding of a Hydropower Producer under Uncertainty: Modified Benders Approach. IEEE Transactions on Power Systems, 33(1), 861-873
Open this publication in new window or tab >>Strategic Bidding of a Hydropower Producer under Uncertainty: Modified Benders Approach
2018 (English)In: IEEE Transactions on Power Systems, ISSN 0885-8950, E-ISSN 1558-0679, Vol. 33, no 1, p. 861-873Article in journal (Refereed) Published
Abstract [en]

This paper proposes a stochastic bilevel program for strategic bidding of a hydropower producer. The price, quantity and ramp-rate bids are considered. The uncertainty of wind power generation, variation of inflows for the hydropower producer, and demand variability are modeled through the moment-matching scenario generation technique. Using discretization the stochastic bilevel program is reformulated as a stochastic mixed-integer linear program (MILP) with disjunctive constraints. We propose a modified Benders decomposition algorithm (MBDA), which fully exploits the disjunctive structure of reformatted MILP model. More importantly, the MBDA does not require optimal tuning of disjunctive parameters and it can be efficiently parallelized. Through an illustrative 5-node example, we identify possible strategies (specific to a hydropower producer) for maximizing profit, which in turn leads to market insights. We also use the IEEE 24-node, 118-node, and 300-node case studies to show how our parallelized MBDA outperforms the standard benders decomposition algorithm. The parallelized MBDA is also compared to the state-of-the-art CPLEX solver.

Place, publisher, year, edition, pages
Institute of Electrical and Electronics Engineers (IEEE), 2018
Keywords
Disjunctive constraint, modified benders decomposition algorithm, stochastic bilevel program
National Category
Other Electrical Engineering, Electronic Engineering, Information Engineering
Identifiers
urn:nbn:se:kth:diva-207089 (URN)10.1109/TPWRS.2017.2696058 (DOI)000418776400076 ()
Note

QC 20170519

Available from: 2017-05-15 Created: 2017-05-15 Last updated: 2018-01-17Bibliographically approved
Yuan, Z., Hesamzadeh, M. R., Wogrin, S. & Baradar, M. (2017). Stochastic Optimal Operationof VSC-MTDC System and FACTS Considering Large-Scale Integration of Wind Power.
Open this publication in new window or tab >>Stochastic Optimal Operationof VSC-MTDC System and FACTS Considering Large-Scale Integration of Wind Power
2017 (English)Manuscript (preprint) (Other academic)
National Category
Electrical Engineering, Electronic Engineering, Information Engineering
Research subject
Electrical Engineering
Identifiers
urn:nbn:se:kth:diva-227300 (URN)
Note

QC 20180522

Available from: 2018-05-07 Created: 2018-05-07 Last updated: 2018-05-22Bibliographically approved
Tohidi, Y. & Hesamzadeh, M. R. (2016). A mathematical model for strategic generation expansion planning. In: IEEE Power and Energy Society General Meeting: . Paper presented at 2016 IEEE Power and Energy Society General Meeting, PESGM 2016, 17 July 2016 through 21 July 2016. IEEE
Open this publication in new window or tab >>A mathematical model for strategic generation expansion planning
2016 (English)In: IEEE Power and Energy Society General Meeting, IEEE, 2016Conference paper, Published paper (Refereed)
Abstract [en]

This paper proposes a mathematical model for strategic generation expansion planning problem. The model is developed based on the the simultaneous-move game between Gencos. Gencos investment decisions are passed to the dispatch center which decides about the production level in operating scenarios considered. Using Karush-Kuhn-Tucker conditions (KKTs) and disjunctive linearization, the model is formulated as a mixed-integer linear program (MILP). The concepts of worst Nash equilibrium (WNE) and best Nash equilibrium (BNE) are introduced to handle multiple NE problem. The impact of uncertainty (scenarios) on equilibria band, i.e., the difference between WNE and BNE is discussed. The developed model is simulated on illustrative 2-node and 3-node example systems and also on IEEE-RTS96 test system.

Place, publisher, year, edition, pages
IEEE, 2016
Keywords
Generation planning, Mixed-integer linear program, Nash equilibrium, Computation theory, Game theory, Investments, Generation expansion planning, Generation expansion planning problem, Investment decisions, Karush Kuhn tucker condition, Mixed integer linear program, Nash equilibria, Production level, Integer programming
National Category
Embedded Systems
Identifiers
urn:nbn:se:kth:diva-202147 (URN)10.1109/PESGM.2016.7741960 (DOI)000399937903124 ()2-s2.0-85002141911 (Scopus ID)9781509041688 (ISBN)
Conference
2016 IEEE Power and Energy Society General Meeting, PESGM 2016, 17 July 2016 through 21 July 2016
Note

QC 20170313

Available from: 2017-03-13 Created: 2017-03-13 Last updated: 2017-06-15Bibliographically approved
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