@article{medeiros_marangon-lima_queiroz_marangon-lima_santos_barbosa_alvares_2022, title={Efficiency analysis for performance evaluation of electric distribution companies}, volume={134}, ISSN={["1879-3517"]}, DOI={10.1016/j.ijepes.2021.107430}, abstractNote={In power systems, the electricity distribution sector requires proper regulation to guarantee power supply security, electricity tariffs modicity and universal service to customers. Generally, electric utilities operate differently and are distinguished in terms of costs, quality of supply, market and network size, and other aspects, that affect their efficiency. In this context, the Data Envelopment Analysis has been used in electricity distribution regulation to define efficiency scores and compare practices. The Data Envelopment Analysis application sometimes comes with weight restrictions and negative variables that modify the original methodology which affects the efficiency scores. The main goal of this paper is to evaluate weights restrictions influence on efficiencies results and to perform a sensitivity analysis of efficiency scores using additional benchmarking techniques. We apply the Cross-Efficiency Analysis and the Ratio-based Efficiency Analysis benchmarking methods, in order to provide relevant quantitative information to compute relative efficiency scores and perform peer evaluations among utilities even if they are outside of the efficient frontier. The Brazilian electricity distribution system is selected as study case. Brazil has strong diversity in terms of economic development, climate and geography, and the current procedure adopted by the regulator determine efficiency metrics for all distribution companies based on their operation cost. Results from our analysis show that the diversity of concession areas significantly influence the stability of efficiency scores. Moreover, considering the approach proposed here it is possible to identify an efficiency relationship among all the distribution companies and not only using the ones that are in the efficiency frontier.}, journal={INTERNATIONAL JOURNAL OF ELECTRICAL POWER & ENERGY SYSTEMS}, author={Medeiros, Giulia O. S. and Marangon-Lima, Luana M. and Queiroz, Anderson R. and Marangon-Lima, Jose W. and Santos, Lorena C. B. and Barbosa, Maria A. and Alvares, Jairo E.}, year={2022}, month={Jan} }
 @article{sioshansi_denholm_arteaga_awara_bhattacharjee_botterud_cole_cortes_queiroz_decarolis_et al._2022, title={Energy-Storage Modeling: State-of-the-Art and Future Research Directions}, volume={37}, ISSN={["1558-0679"]}, DOI={10.1109/TPWRS.2021.3104768}, abstractNote={Given its physical characteristics and the range of services that it can provide, energy storage raises unique modeling challenges. This paper summarizes capabilities that operational, planning, and resource-adequacy models that include energy storage should have and surveys gaps in extant models. Existing models that represent energy storage differ in fidelity of representing the balance of the power system and energy-storage applications. Modeling results are sensitive to these differences. The importance of capturing chronology can raise challenges in energy-storage modeling. Some models ‘decouple’ individual operating periods from one another, allowing for natural decomposition and rendering the models relatively computationally tractable. Energy storage complicates such a modeling approach. Improving the representation of the balance of the system can have major effects in capturing energy-storage costs and benefits.}, number={2}, journal={IEEE TRANSACTIONS ON POWER SYSTEMS}, author={Sioshansi, Ramteen and Denholm, Paul and Arteaga, Juan and Awara, Sarah and Bhattacharjee, Shubhrajit and Botterud, Audun and Cole, Wesley and Cortes, Andres and Queiroz, Anderson de and DeCarolis, Joseph and et al.}, year={2022}, month={Mar}, pages={860–875} }
 @article{patankar_eshraghi_queiroz_decarolis_2022, title={Using robust optimization to inform US deep decarbonization planning}, volume={42}, ISSN={["2211-4688"]}, DOI={10.1016/j.esr.2022.100892}, abstractNote={US energy system development consistent with the Paris Agreement will depend in part on future fuel prices and technology costs, which are highly uncertain. Energy system optimization models (ESOMs) represent a critical tool to examine clean energy futures under different assumptions. While many approaches exist to examine future sensitivity and uncertainty in such models, most assume that uncertainty is resolved prior to the model run. Policy makers, however, must take action before uncertainty is resolved. Robust optimization represents a method that explicitly considers future uncertainty within a single model run, yielding a near-term hedging strategy that is robust to uncertainty. This work focuses on extending and applying robust optimization methods to Temoa, an open source ESOM, to derive insights about low carbon pathways in the United States. A robust strategy that explicitly considers future uncertainty has expected savings in total system cost of 12% and an 8% reduction in the standard deviation of expected costs relative to a strategy that ignores uncertainty. The robust technology deployment strategy also entails more diversified technology mixes across the energy sectors modeled. • We apply correlated robust optimization (RO) to examine US energy futures. • We propose a method to form the RO uncertainty set that considers autocorrelation. • The RO approach encourages resource diversification to hedge against uncertainty. • The robust strategy includes CCS, solar thermal, and underground hydrogen storage. • Pursuing a robust technology deployment strategy has economic benefits.}, journal={ENERGY STRATEGY REVIEWS}, author={Patankar, Neha and Eshraghi, Hadi and Queiroz, Anderson Rodrigo and DeCarolis, Joseph F.}, year={2022}, month={Jul} }
 @article{faria_queiroz_lima_lima_silva_2021, title={An assessment of multi-layer perceptron networks for streamflow forecasting in large-scale interconnected hydrosystems}, volume={19}, ISSN={["1735-2630"]}, url={http://www.scopus.com/inward/record.url?eid=2-s2.0-85111100097&partnerID=MN8TOARS}, DOI={10.1007/s13762-021-03565-y}, number={7}, journal={INTERNATIONAL JOURNAL OF ENVIRONMENTAL SCIENCE AND TECHNOLOGY}, author={Faria, V. A. D. and Queiroz, A. R. and Lima, L. M. and Lima, J. W. M. and Silva, B. C.}, year={2021}, month={Jul} }
 @article{henry_eshraghi_lugovoy_waite_decarolis_farnham_ruggles_peer_wu_queiroz_et al._2021, title={Promoting reproducibility and increased collaboration in electric sector capacity expansion models with community benchmarking and intercomparison efforts}, volume={304}, ISSN={["1872-9118"]}, DOI={10.1016/j.apenergy.2021.117745}, abstractNote={Electric sector capacity expansion models are widely used by academic, government, and industry researchers for policy analysis and planning. Many models overlap in their capabilities, spatial and temporal resolutions, and research purposes, but yield diverse results due to both parametric and structural differences. Previous work has attempted to identify some differences among commonly used capacity expansion models but has been unable to disentangle parametric from structural uncertainty. Here, we present a model benchmarking effort using highly simplified scenarios applied to four open-source models of the U.S. electric sector. We eliminate all parametric uncertainty through using a common dataset and leave only structural differences. We demonstrate how a systematic model comparison process allows us to pinpoint specific and important structural differences among our models, including specification of technologies as baseload or load following generation, battery state-of-charge at the beginning and end of a modeled period, application of battery roundtrip efficiency, treatment of discount rates, formulation of model end effects, and digit precision of input parameters. Our results show that such a process can be effective for improving consistency across models and building model confidence, substantiating specific modeling choices, reporting uncertainties, and identifying areas for further research and development. We also introduce an open-source test dataset that the modeling community can use for unit testing and build on for benchmarking exercises of more complex models. A community benchmarking effort can increase collaboration among energy modelers and provide transparency regarding the energy transition and energy challenges, for other stakeholders such as policymakers.}, journal={APPLIED ENERGY}, author={Henry, Candise L. and Eshraghi, Hadi and Lugovoy, Oleg and Waite, Michael B. and DeCarolis, Joseph F. and Farnham, David J. and Ruggles, Tyler H. and Peer, Rebecca A. M. and Wu, Yuezi and Queiroz, Anderson and et al.}, year={2021}, month={Dec} }
 @article{esraghi_queiroz_sankarasubramanian_decarolis_2021, title={Quantification of climate-induced interannual variability in residential U.S. electricity demand}, volume={236}, ISSN={["1873-6785"]}, DOI={10.1016/j.energy.2021.121273}, abstractNote={We assess the sensitivity of residential electricity demand in 48 U S. states to seasonal climate variations and structural changes pertaining to state-level household electricity demand. The main objective is to quantify the effects of seasonal climate variability on residential electricity demand variability during the winter and summer seasons. We use state-level monthly demographic, energy, and climate data from 2005 to 2017 in a linear regression model and find that interannual climate variability explains a significant share of seasonal household electricity demand variation: in 42 states, more than 70% and 50% of demand variability in summer and winter, respectively, is driven by climate. Our work suggests the need for new datasets to quantify unexplained variance in the winter and summer electricity demand. Findings from this study are critical to developing seasonal electricity demand forecasts, which can aid power system operation and management, particularly in a future with greater electrification of end-use demands.}, journal={Energy}, author={Esraghi, H. and Queiroz, Ade and Sankarasubramanian, A. and DeCarolis, J.}, year={2021}, month={Dec}, pages={121273} }
 @article{cawthorne_rodrigo de queiroz_eshraghi_sankarasubramanian_decarolis_2021, title={The Role of Temperature Variability on Seasonal Electricity Demand in the Southern US}, volume={3}, ISSN={["2624-9634"]}, DOI={10.3389/frsc.2021.644789}, abstractNote={The reliable and affordable supply of energy through interconnected systems represent a critical infrastructure challenge. Seasonal and interannual variability in climate variables—primarily precipitation and temperature—can increase the vulnerability of such systems during climate extremes. The objective of this study is to understand and quantify the role of temperature variability on electricity consumption over representative areas of the Southern United States. We consider two states, Tennessee and Texas, which represent different climate regimes and have limited electricity trade with adjacent regions. Results from regression tests indicate that regional population growth explains most of the variability in electricity demand at decadal time scales, whereas temperature explains 44–67% of the electricity demand variability at seasonal time scales. Seasonal temperature forecasts from general circulation models are also used to develop season-ahead power demand forecasts. Results suggest that the use of climate forecasts can potentially help to project future residential electricity demand at the monthly time scale. Capsule Summary: Seasonal temperature forecasts from GCMs can potentially help in predicting season-ahead residential power demand forecasts for states in the Southern US.}, journal={Frontiers in Sustainable Cities}, author={Cawthorne, D. and Rodrigo de Queiroz, A. and Eshraghi, H. and Sankarasubramanian, A. and DeCarolis, J.F.}, year={2021}, month={Jun} }
 @article{sodano_decarolis_queiroz_johnson_2021, title={The symbiotic relationship of solar power and energy storage in providing capacity value}, volume={177}, ISSN={["1879-0682"]}, DOI={10.1016/j.renene.2021.05.122}, abstractNote={Ensuring power system reliability under high penetrations of variable renewable energy is a critical task for system operators. In this study, we use a loss of load probability model to estimate the capacity credit of solar photovoltaics and energy storage under increasing penetrations of both technologies, in isolation and in tandem, to offer new understanding on their potential synergistic effects. Increasing penetrations of solar PV alter the net load profile on the grid, shifting the peak net load to hours with little or no solar generation and leading to diminishing capacity credits for each additional increment of solar. However, the presence of solar PV decreases the duration of daily peak demands, thereby allowing energy-limited storage capacity to dispatch electricity during peak demand hours. Thus, solar PV and storage exhibit a symbiotic relationship when used in tandem. We find that solar PV and storage used together make a more significant contribution to system reliability: as much as 40% more of the combined capacity can be counted on during peak demand hours compared to scenarios where the two technologies are deployed separately. Our test case demonstrates the important distinction between winter and summer peaking systems, leading to significantly different seasonal capacity values for solar PV. These findings are timely as utilities replace their aging peaking plants and are taking energy storage into consideration as part of a low carbon pathway.}, journal={RENEWABLE ENERGY}, author={Sodano, Daniel and DeCarolis, Joseph F. and Queiroz, Anderson Rodrigo and Johnson, Jeremiah X.}, year={2021}, month={Nov}, pages={823–832} }
 @article{moreira santos_lima_silva pereira_osis_santos medeiros_queiroz_flauzino_paschoal correa cardoso_czank junior_santos_et al._2019, title={Optimizing routing and tower spotting of electricity transmission lines: An integration of geographical data and engineering aspects into decision-making}, volume={176}, ISSN={["1873-2046"]}, DOI={10.1016/j.epsr.2019.105953}, abstractNote={Abstract In many parts of the world, electric sectors are already experiencing considerable rising in generation from renewable energy sources. Large amounts of new generation are expected in the near-term future, which will require additional transmission investments to properly integrate these resources into the existing electric power system. The transmission expansion planning has an important role in this environment in order to guarantee the security of the supply with the required levels of quality and price. Therefore, the implementation of new transmission lines (TL) must be fast and accurate in order to avoid delays to connect new power sources and potential supply and reliability problems. In this sense, Geographical Information Systems (GIS) can be a powerful tool that provides decision support techniques, which enables a transparent, sustainable, faster planning process for TLs in power systems. This paper presents a novel approach for the design of overhead TLs, considering geographical, engineering and cost aspects into the decision-making process. For this, routing and tower spotting optimization approaches are integrated into the proposed methodology, which is divided into three main steps: (i) Route Guideline Definition based on a raster-based least-cost path approach; (ii) Vertex Siting based on graph theory and the Dijkstra shortest path algorithm, applied in order to find the optimal vertex set along the route guideline; (iii) Tower Spotting based on Dynamic Programming, which is applied in order to find the optimal distribution of towers along the topographical profile of the route obtained in the previous step. The proposed methodology is focused on preliminary planning and decision-making for TL auctions, where the objective is to find design alternatives with the least cost. We show a case study using the proposed methodology for a real project of a 525 kV TL that interconnects Machadinho and Campos Novos (located in the Santa Catarina state in Brazil). The outcomes show that the proposed approach is capable of representing the technical and geographical constraints of a TL design, providing results with lower costs when compared to the original TL design.}, journal={ELECTRIC POWER SYSTEMS RESEARCH}, author={Moreira Santos, Afonso Henriques and Lima, Rodolfo Mendes and Silva Pereira, Camilo Raimundo and Osis, Reinis and Santos Medeiros, Giulia Oliveira and Queiroz, Anderson Rodrigo and Flauzino, Barbara Karoline and Paschoal Correa Cardoso, Arthur Rohr and Czank Junior, Luiz and Santos, Renato Antonio and et al.}, year={2019}, month={Nov} }
 @article{aquila_peruchi_rotela junior_souza rocha_queiroz_pamplona_balestrassi_2018, title={Analysis of the wind average speed in different Brazilian states using the nested GR & R measurement system}, volume={115}, ISSN={["1873-412X"]}, DOI={10.1016/j.measurement.2017.10.048}, abstractNote={Abstract Brazil presents remarkable potential for wind power generation. This study aims to evaluate the behavior of wind average speed at the four major wind energy-producing states. The main contribution of this research is to use the NGR&R study (Nested Gage Repeatability & Reproducibility), generally applied on manufacturing quality management. Wind average speeds were collected for each month in four states, between the years of 2012 and 2015. Seasonality impact, measurements recurrence over the years and difference between states on wind average speed were assessed in this research. Time series, boxplot and control charts have been used to investigate not only wind average speed between months and states, but also range variation for each state by month. Study results show that the impact of these three factors is statistically significant and that the different location of these states presents the most relevant impact to wind mean speed variation in the country.}, journal={MEASUREMENT}, author={Aquila, Giancarlo and Peruchi, Rogerio Santana and Rotela Junior, Paulo and Souza Rocha, Luiz Celio and Queiroz, Anderson Rodrigo and Pamplona, Edson de Oliveira and Balestrassi, Pedro Paulo}, year={2018}, month={Feb}, pages={217–222} }
 @article{faria_queiroz_lima_lima_2018, title={Cooperative game theory and last addition method in the allocation of firm energy rights}, volume={226}, ISSN={["1872-9118"]}, url={http://dx.doi.org/10.1016/j.apenergy.2018.06.065}, DOI={10.1016/j.apenergy.2018.06.065}, abstractNote={The firm energy rights of a hydro plant is a parameter used in some electricity markets to define the maximum amount of energy that a power plant can trade through contracts. In a centralized dispatch scheme, the coordinated operation of the hydro plants generates a synergetic gain in the system firm energy, in this setting, a question that often arises is how to fairly allocate this energy among each hydro plant. This work proposes a formulation to compute the firm energy rights of hydro plants using cooperative game theory and the last addition allocation method. The main goal is to integrate the interests of hydro agents with the needs of the regulatory agencies, searching in the core of the game for solutions that give the right incentives to the optimal system development. In order to make simulations of real instances possible, it is proposed a reformulation of the traditional mixed integer linear programming model that computes the core constraints, which induces a significant speed-up of the algorithm solution time. It is shown an application of the proposed methodology to a real instance representing the Brazilian electric power system.}, journal={APPLIED ENERGY}, author={Faria, Victor. A. D. and Queiroz, Anderson Rodrigo and Lima, Luana M. M. and Lima, Jose W. M.}, year={2018}, month={Sep}, pages={905–915} }
 @article{fonseca_pamplona_queiroz_mello valerio_aquila_silva_2018, title={Multi-objective optimization applied for designing hybrid power generation systems in isolated networks}, volume={161}, ISSN={["0038-092X"]}, DOI={10.1016/j.solener.2017.12.046}, abstractNote={Abstract The use of hybrid power generation systems is an attractive alternative to conventional fossil fuel generation since they may assist in mitigating the emission of gases that are harmful to the atmosphere when using clean and renewable sources of energy. However, finding the ideal configuration for the installation of a hybrid system composed of solar photovoltaic (PV)-diesel generation is a complex task. In this sense, the objective of this study is to develop an approach to select the optimal configuration of hybrid power generation systems for isolated regions by means of combining the techniques of Mixing Design of Experiments, Normal Boundary Intersection and analysis of super efficiency using Data Envelopment Analysis. The proposed approach is applied to a set of four isolated regions in the northern region of Brazil, more specifically in the state of Amazonas. The results show that for each region a different configuration is selected but with large shares of diesel generation at first. On the other hand, all these cases represent points in the Pareto frontier that are the most inefficient due to the high volume of CO2 emissions. From the application of the proposed approach, significant CO2 emission reductions are obtained by selecting the optimal configurations represented as the most efficient points in the Pareto frontier. Our results show that due to conflicting characteristics of the selected objectives, the installation of such hybrid power generation systems produces an increase in LCOE, mainly related to the high costs of the batteries, although less accentuated than the reductions in emissions.}, journal={SOLAR ENERGY}, author={Fonseca, Marcelo Nunes and Pamplona, Edson de Oliveira and Queiroz, Anderson Rodrigo and Mello Valerio, Victor Eduardo and Aquila, Giancarlo and Silva, Saulo Ribeiro}, year={2018}, month={Feb}, pages={207–219} }
 @misc{aquila_pamplona_queiroz_rotela junior_fonseca_2017, title={An overview of incentive policies for the expansion of renewable energy generation in electricity power systems and the Brazilian experience}, volume={70}, ISSN={["1364-0321"]}, DOI={10.1016/j.rser.2016.12.013}, abstractNote={Abstract Energy production from renewable sources is already a reality in many countries, and with that, different strategies for incentivizing investments in renewable energy generation have been proposed and used over the years. In this study, long-term policies that have been applied in several countries, such as feed-in tariffs, shares with commercialization of certificates, auctions, and net metering, are overviewed and discussed. The main advantages and disadvantages of these incentive strategies are emphasized, focusing on applications. Some of these strategies that have already been applied in Brazil are analyzed in greater depth, emphasizing the potentialities and fragilities of these mechanisms observed within the country. Even though it is a country that stands out in relation to other Latin American countries regarding electricity generation from non-hydro renewable sources, Brazil still faces barriers that prevent a utilization compatible with its potential. Moreover, the trend for renewable sources, such as wind and solar power, is to represent an energy capacity reserve to cover hydrological risks and also to contribute to a distributed generation spread through electricity distribution networks.}, journal={RENEWABLE & SUSTAINABLE ENERGY REVIEWS}, author={Aquila, Giancarlo and Pamplona, Edson de Oliveira and Queiroz, Anderson Rodrigo and Rotela Junior, Paulo and Fonseca, Marcelo Nunes}, year={2017}, month={Apr}, pages={1090–1098} }
 @inproceedings{sun_thomas_singh_li_baran_lubkeman_decarolis_queiroz_white_watts_et al._2017, title={Cost-benefit assessment challenges for a smart distribution system: A case study}, DOI={10.1109/pesgm.2017.8274167}, abstractNote={The FREEDM system is a technology for a smarter and resilient distribution system that facilitates a higher level of distributed energy resource (DER) integration by offering effective voltage regulation, reactive power compensation and real time monitoring and control. This paper provides a framework for conducting a cost-benefit analysis for such a smart distribution system. The method first identifies the benefits, and then quantifies and monetizes them. OpenDSS time-series based power flow simulation is used to quantify the benefits accurately. The costs associated with the new components of the system are estimated based on prototype units. A cost-benefit analysis is adopted to identify the scenarios where employing such a system by a utility becomes economically attractive.}, booktitle={2017 ieee power & energy society general meeting}, author={Sun, L. S. and Thomas, J. and Singh, S. and Li, D. X. and Baran, M. and Lubkeman, David and DeCarolis, J. and Queiroz, A. R. and White, L. and Watts, S. and et al.}, year={2017} }
 @article{li_queiroz_decarolis_bane_he_keeler_neary_2017, title={The economics of electricity generation from Gulf Stream currents}, volume={134}, ISSN={["1873-6785"]}, DOI={10.1016/j.energy.2017.06.048}, abstractNote={Abstract Hydrokinetic turbines harnessing energy from ocean currents represent a potential low carbon electricity source. This study provides a detailed techno-economic assessment of ocean turbines operating in the Gulf Stream off the North Carolina coast. Using hindcast data from a high-resolution ocean circulation model in conjunction with the US Department of Energy's reference model 4 (RM4) for ocean turbines, we examine resource quality and apply portfolio optimization to identify the best candidate sites for ocean turbine deployment. We find that the lowest average levelized cost of electricity (LCOE) from a single site can reach 400 $/MWh. By optimally selecting geographically dispersed sites and taking advantage of economies of scale, the variations in total energy output can be reduced by an order of magnitude while keeping the LCOE below 300 $/MWh. Power take-off and transmission infrastructure are the largest cost drivers, and variation in resource quality can have a significant influence on the project LCOE. While this study focuses on a limited spatial domain, it provides a framework to assess the techno-economic feasibility of ocean current energy in other western boundary currents.}, journal={ENERGY}, author={Li, Binghui and Queiroz, Anderson Rodrigo and DeCarolis, Joseph F. and Bane, John and He, Ruoying and Keeler, Andrew G. and Neary, Vincent S.}, year={2017}, month={Sep}, pages={649–658} }
 @article{aquila_rotela junior_pamplona_queiroz_2017, title={Wind power feasibility analysis under uncertainty in the Brazilian electricity market}, volume={65}, ISSN={["1873-6181"]}, DOI={10.1016/j.eneco.2017.04.027}, abstractNote={Abstract Investors must be able to plan and analyze their investments in order to optimize decisions and turn them into profits associated with a particular project. Since electricity producers in the Brazilian electric power system are exposed to a short-term market, the goal of this paper is to propose a framework for investment analysis capable of encompassing different uncertainties and possibilities for wind power generators in a regulated market, characterized by auctions. In order to reach the proposed objective we employ a simulation technique which allows modeling cash flows considering uncertainties in variables related to project financial premises, electricity generation and producer exposure to the short-term market. For such goal, this study presents a new approach for investment analysis that allows the identification of the main uncertainty parameters and risks associated to this class of projects in the Brazilian electricity market. We also employ the Value at Risk technique to perform a risk management analysis in such context.}, journal={ENERGY ECONOMICS}, author={Aquila, Giancarlo and Rotela Junior, Paulo and Pamplona, Edson de Oliveira and Queiroz, Anderson Rodrigo}, year={2017}, month={Jun}, pages={127–136} }
 @article{queiroz_marangon lima_marangon lima_silva_scianni_2016, title={Climate change impacts in the energy supply of the Brazilian hydro-dominant power system}, volume={99}, ISSN={["1879-0682"]}, DOI={10.1016/j.renene.2016.07.022}, abstractNote={Abstract Over the past few years, there has been a growing global consensus related to the importance of renewable energy to minimize the emission of greenhouse gases. The solution is an increase in the number of renewable power plants but unfortunately, this leads to a high dependence on climate variables which are already affected by climate change. Brazil is one of the largest producers of electricity by renewables through its hydro-dominant power generation system. However, hydro-generation depends on water inflows that are directly affected by climate change that consequently affect the electricity production. Therefore, these changes need to be considered in the operation and planning of a hydro-dominant power system. In this paper, we present the effects of different climate scenarios in the water inflows produced by the regional Eta climate model. Normally, studies use an optimization model to make decisions in case of a hydro-thermal scheduling problem and use the assured energy to evaluate the hydro-production. In this analysis, water inflows used in the optimization process consider different trends according to its associated climate scenario. Our paper shows that climate change may drastically impact the system assured energy and consequently, the system's capability to supply load.}, journal={RENEWABLE ENERGY}, author={Queiroz, Anderson Rodrigo and Marangon Lima, Luana M. and Marangon Lima, Jose W. and Silva, Benedito C. and Scianni, Luciana A.}, year={2016}, month={Dec}, pages={379–389} }
 @article{lima_osis_queiroz_moreira santos_2016, title={Least-cost path analysis and multi-criteria assessment for routing electricity transmission lines}, volume={10}, ISSN={["1751-8695"]}, DOI={10.1049/iet-gtd.2016.1119}, abstractNote={The classical approach for transmission line (TL) routing based on paper maps, aerial photographs and field visits can generate inconsistent results, besides being a time consuming and intensive labour activity. The application of methodologies based on geographic information system (GIS) combined with multi-criteria assessment (MCA) methods can generate time and cost savings on the planning step. However, this methodology still must be better assessed for its applicability and improvements can be made. Therefore, this study aims at verifying the applicability of a GIS methodology for TL routing using analytic hierarchy process (AHP) for weighting criteria. In addition, the effectiveness of AHP method is evaluated comparing the previously attained results with a route modelled using monetary values to weight the criteria. To achieve the objectives, the methodology is applied for an area in the northern region of Brazil (state of Para) where a 230 kV TL is already implemented: the TL Vila do Conde-Castanhal. As a result, routes with lower length and lower total cost than the implemented TL were obtained, which suggest the potential benefits of applying the proposed methodology compared with traditional route planning, which does not use quantitative MCA and more advanced GIS tools.}, number={16}, journal={IET GENERATION TRANSMISSION & DISTRIBUTION}, author={Lima, Rodolfo Mendes and Osis, Reinis and Queiroz, Anderson Rodrigo and Moreira Santos, Afonso Henriques}, year={2016}, month={Dec}, pages={4222–4230} }
 @misc{queiroz_2016, title={Stochastic hydro-thermal scheduling optimization: An overview}, volume={62}, ISSN={["1879-0690"]}, DOI={10.1016/j.rser.2016.04.065}, abstractNote={Abstract This paper presents an overview about the hydro-thermal scheduling problem. In an electrical power system power generators have to be scheduled over a time horizon in order to supply system demand. The scheduling problem consists in dispatching the available generators to meet the system electric load while minimizing the operational costs related to fuel and possible load curtailments. In a system with a large share of hydro generation, different from a thermal dominant power system, the uncertainty of water inflows play an important role in the decision-making process. In this setting the scheduling of generators has to be determined considering different future possibilities for water availability. Also, in the existence of a cascade system, the availability of water to produce electricity in hydro plants is influenced by decisions taken in upstream reservoirs. These issues complicate the hydro-thermal scheduling problem that often in the literature is modeled as a multi-stage stochastic program. In this paper we aim to give an overview about the main ideas behind this problem. We present model formulations, a solution technique, and point out to new developments related to this research.}, journal={RENEWABLE & SUSTAINABLE ENERGY REVIEWS}, author={Queiroz, Anderson Rodrigo}, year={2016}, month={Sep}, pages={382–395} }
 @article{aquila_souza rocha_rotela junior_pamplona_queiroz_paiva_2016, title={Wind power generation: An impact analysis of incentive strategies for cleaner energy provision in Brazil}, volume={137}, ISSN={["1879-1786"]}, DOI={10.1016/j.jclepro.2016.07.207}, abstractNote={Brazil has adopted various strategies to encourage alternative renewable energy sources in pursuit of cleaner and sustainable energy production. To this end, strategies should support the reduction of the financial risk for potential investors in the renewable energy market. Therefore, this study aims to analyze the impact of incentive strategies on the financial risk of wind power generation projects in Brazil in different marketing environments. From a quantitative approach, using Monte Carlo Simulation in three scenarios, we evaluate the impact of funding from the National Development Bank and participation in the Clean Development Mechanism in the financial returns of the investor in a regulated contracting environment and free contracting environment, measured by the Net Present Value. We conduct a statistical analysis to find out if there were statistically significant differences in investor risk in each scenario. The main results of the study are as follows: the wind speed, the selling price of energy, and disbursement for the investment have the most significant impact on the financial return; the project viability probability is greater than 85% in all scenarios, regardless of the marketing environment; the regulated market is less risky for the producer than the free market, since there is a statistically significant difference in Net Present Value variances for all scenarios; in the regulated contracting environment, funding is critical to reducing risk; and carbon credit trading is not a suitable policy for providing financial security to renewable energy producers. Thus, we conclude that in Brazil the contracting of projects from auctions in the regulated contracting environment, with the support of the National Development Bank, has been important for neutralizing the producer's financial risks.}, journal={JOURNAL OF CLEANER PRODUCTION}, author={Aquila, Giancarlo and Souza Rocha, Luiz Celio and Rotela Junior, Paulo and Pamplona, Edson de Oliveira and Queiroz, Anderson Rodrigo and Paiva, Anderson Paulo}, year={2016}, month={Nov}, pages={1100–1108} }