An optimal pricing scheme in electricity markets by parallelizing security constrained optimal power flow based market-clearing model

To improve economic efficiency of electricity markets, the market-clearing model must be designed to give transparent information for pricing system security and to quantify the correlation between the market operations and the power systems operations, which is an immensely provocative and challenging issue in electricity markets. This paper sets out to propose a novel approach to pricing the system security by parallelizing the security constrained optimal power flow (SCOPF) based market-clearing model, while providing market solutions as a function of complying with the required voltage security margin and N-1 contingency criteria. The proposed SCOPF based market-clearing framework also takes into consideration the bilateral transaction information and, at the same time, optimal pricing expressions through computing locational marginal prices (LMPs) and nodal congestion prices (NCPs) for ensuring voltage security are derived. The results from a 129-bus model of the Italian HV transmission system turn out to be the validity of the proposed market-clearing model for managing and pricing the system security.     

电力现货市场环境下提供位置信号电价机制的协同作用

对电价中的位置信号及能够提供位置信号的电价机制进行分类梳理和总结,对电力现货市场环境下电价中位置信号的作用进行分析;结合电力现货市场仿真,定量分析在不同的电网结构及系统阻塞条件下,电能量现货市场中的“节点边际电价（LMP）机制”和“分区输电定价”机制在实现其作为公共事业服务价格作用方面的协同作用关系;结合中国某省电网的实际情况,通过电力现货市场仿真和电价测算对分析结果进行验证,为中国电力现货市场环境下的电价机制选择提出建议。     

电力现货市场环境下提供位置信号电价机制的协同作用

对电价中的位置信号及能够提供位置信号的电价机制进行分类梳理和总结,对电力现货市场环境下电价中位置信号的作用进行分析;结合电力现货市场仿真,定量分析在不同的电网结构及系统阻塞条件下,电能量现货市场中的“节点边际电价（LMP）机制”和“分区输电定价”机制在实现其作为公共事业服务价格作用方面的协同作用关系;结合中国某省电网的实际情况,通过电力现货市场仿真和电价测算对分析结果进行验证,为中国电力现货市场环境下的电价机制选择提出建议。     

电力市场中基于序贯仿真的用户电价研究

在厂网分开的电力市场中，用户电价不仪与电厂报价和电网支出有关，还与系统的可靠水平有关。电网运行方式、负荷水平、设备的检修和随机故障，都对用户电价和电网收益产生重要影响。本文采用时间序列负荷模型，在电网运行中考虑了运行方式、负荷水平和设备停运，采用序贯仿真模拟电网的长期运行，建立优化调度策略，引入停电赔偿电价和峰谷电价，计算相应的收支费用。在IEEE-14测试系统的计算结果表明，算法反映了安全因素和经济因素的关系，有助于建立电力市场中合理的用户电价体系。     

考虑可中断负荷和需求侧竞价的供电电价模型研究

需求响应(DR)是需求侧管理在竞争性电力市场中的发展,已引起电力部门和用户的广泛关注。以需求侧开放的电力市场为背景,在基于原-对偶内点法最优潮流的实时电价算法基础上,考虑用户参与可中断负荷和需求侧竞价项目对系统负荷的影响,建立了计及需求响应的供电电价模型。IEEE14节点算例表明了该模型的有效性,计算结果分析也验证了需求响应可平缓供电电价。     

集成定价法在输电电价中的应用

对输电电价的定价方法进行了研究,对输电网的成本进行了分析,将其成本分为固定成本和变动成本2大类,固定成本基本上不随时间变化,变动成本随时间变化而不断改变。提出了集成定价思想,即对输电网的固定成本采用综合成本定价法,按最大需量进行分摊,而对变动成本则采用基于边际成本定价法的实时电价并进行实时分摊,两者有效结合即得出输电网的电价模型。该模型可称为集成定价法下的节点电价模型,可以应用于实时电价、分时电价、日前市场电价和远期合同电价。通过算例说明了该电价模型的具体应用。     

Optimal demand-side response to electricity spot prices forstorage-type customers

The customer response to spot prices is discussed. The factors that allow flexible customer response without service curtailments are identified. An overview of a fast, optimal, nonsimplex algorithm applicable to single storage electricity consuming processes is presented. A case study involving an air compression company demonstrates the application of the algorithm and shows the economic effects of industrial customer response to the spot pricing of electricity     

Decomposition model and interior point methods for optimal spotpricing of electricity in deregulation environments

In this paper, an integrated optimal spot pricing model is presented first. The proposed model includes the detailed derivation of optimal nodal specific real-time prices for active and reactive powers, and the method to decompose them into different components corresponding to generation, loss, and many selected ancillary services such as spinning reserve, voltage control and security control. The features of the proposed model are discussed in relationship to existing pricing models and classical economic dispatch. The model is then implemented by modifying existing Newton OPF methods through interior point algorithms, which can effectively avoid “go” “no go” gauge (i.e. highly volatile) in the calculation of spot prices. Case studies on 5-bus and IEEE 30-bus systems are reported to illustrate the proposed method     

A method for optimal pricing of electric supply including transmission system considerations

Determining real-time electricity rate structures is currently receiving a great deal of attention. In this paper, a strategy for pricing electricity supply is formulated and evaluated. Unlike other methods which use only the variation of fuel cost for generation to estimate the rate structures, the proposed pricing algorithm incorporates the optimal allocation of transmission system operating costs based on time-of-use pricing. The transmission costs are obtained by assigning a price k to each unit of power flow in the network. The assignment does not discriminate between participants located at differing parts of the network. The real-time pricing reflects the instantaneous cost of production and functions as a load management tool because this interacts with consumer behavior. The demand for power flows and transmission on an electricity supply system, like the demand for any bundle of economic goods depends upon the assigned transmission prices, together with the economic benefit to the consumer. It is assumed that there are no privately owned generating plants and that all plants and transmission lines are operated by the utility. The modeling scheme is applied to the IEEE standard 5, 14, 30 and 57 bus power systems and involves solving a modified optimal power flow problem (OPF) iteratively using the MINOS package. It is concluded that the method has a wide potential application in electricity supply pricing.     

How would real-time electricity pricing affect the Saudi power sector in the long-run?

This paper shows the effects of real-time electricity pricing (RTP) on the long-run marginal costs of power generation in Saudi Arabia. To do this, it links a multi-sector energy system model with a residential electricity use model. The energy system model contains an economic power dispatch optimization component. The residential framework embeds households, whose decisions are governed by microeconomic principles, in a physical building energy model. The analysis entails liberalizing fuel prices for the power utilities and setting the dynamic prices of electricity equal to the long-run marginal electricity supply costs. The electricity prices are solely offered to households. The key takeaways from this analysis are:

• •RTP, a form of dynamic electricity pricing, reduces the variability of the marginal costs for Saudi power utilities throughout the day.
• •Lowered capital spending by the Saudi power sector results from RTP and consequently lower power loads. Moreover, the curtailed investment in power plants would more than cover the costs of residential smart meter replacements.

     

Energy and reserve pricing in security and network-constrained electricity markets

This paper analyzes some unresolved pricing issues in security-constrained electricity markets subject to transmission flow limits. Although the notion of separate reserve types as proposed by FERC can be precisely and unambiguously defined, when transmission constraints are active, the very existence of separate reserve prices and markets is open to question when the prices are based on marginal costs. Instead, we submit here that the only products whose marginal costs can be separately and uniquely defined and calculated are those of energy and security at each node. Thus, under marginal pricing, at any given network bus all scheduled reserve types should be priced not at separate rates but at a common rate equal to the marginal cost of security at that bus. Furthermore, we argue that nodal or area reserves cannot be prespecified but must be obtained as by-products of the market-clearing process. Simulations back up these conclusions.     

Inversion of real time spot prices in the direction of real powerflow in a transmission line

An increasing number of electricity markets employing some form of spot pricing. However, limited experience of the behavior of spot prices exists. This paper introduces and investigates one particular aspect of pricing behavior observed in the New Zealand spot market, known as “price inversion”. Spot prices are generally calculated using some form of OPF or power-flow software. The phenomena of price inversion is investigated using the DC power-flow implemented in the New Zealand spot market, and using a full AC power-flow. Price inversion is shown to be dependent on the physical characteristics of the power system. The economic implications of price inversion are also discussed     

解除管制的电力零售市场实时电价研究

零售侧打破垄断引入竞争是电力市场发展的趋势,制定合理的零售电价是市场开放的关键.根据电力零售市场的特点,基于负荷价格响应的定义以及边际成本定价理论,推导出了考虑负荷价格响应的有功实时电价的表达式.以社会成本最大化为目标函数,建立了考虑负荷价格响应特性的最优潮流模型,从而求解出未来引入竞争的电力零售市场中电力库交易模式下的实时电价.采用32节点配电系统对所提方法进行仿真,结果证明为促进零售市场竞争、引导用户合理用电提供了合理有效的定价方法.     

Development of a hybrid model for electrical power spot prices

A great deal of interest has been paid to the market-based pricing of electrical power. Electrical power contracts often contain embedded options, the valuations of which require a stochastic model for electricity prices. Successful stochastic models exist for modeling price variations in traditional commodities. Electricity is critically different from these commodities as it is difficult to store and, on short time scales, its price is highly inelastic. This has important implications for stochastic spot price models of electricity. Several stochastic models of electricity spot prices already exist. In these random models, price returns play a dominant role. In this paper, we lead a guided tour through existing electricity price data to motivate a new stochastic electricity price model different in that it directly models price. We apply the new model to the problem of pricing options on electrical power and discuss these preliminary results     

电力金融市场综述

电力金融市场是电力现货市场发展的必然产物,它有利于发现电力真实的价格,促进电力市场公平竞争;并能为市场交易者提供风险管理工具,抑止现货电价飞升,有利于电力市场的稳定。电力金融市场的研究对于设计高效、合理的中国电力市场框架和电力交易机制有着重要的参考价值。文中在介绍各国电力金融市场的基础上对电力金融产品进行归类研究,包括电力期货和电力期权的分类。着重论述了电力金融市场的2个关键问题:电力期货的套期保值策略和电力期权的定价方法,推导了电力期货的动态和静态最优保值率公式和电力期权基于BlackScholes模型和MonteCarlo模拟的定价公式。通过对现有研究的分析和评论,最后提出了电力金融市场方面几个重要的研究领域。     

Real-Time Differential Pricing Scheme for Active Consumers with Electric Vehicles

Electric vehicles (EVs) are becoming increasingly popular because of their low operating costs. However, the anticipated increase in EV usage presents opportunities as well as challenges for utilities. This paper models EV charging behavior of active consumers who strategize their EV charging schedule to minimize the charging cost. The electric utility employs a temporal and spatially varying real-time pricing scheme that minimizes peak-to-average load ratio by influencing charging behavior of multiple active consumers. These active consumers decide their optimal charging strategy based on real-time electricity prices in order to minimize their EV charging cost. A model predictive control (MPC)-based optimal pricing scheme for electric utility and optimal charging strategy for active consumers is proposed. Effects of the proposed approach on load profile is verified using simulations.     

Cutting through complexity: Why did Australian electricity prices skyrocket,and are recent reforms a useful solution?

The main causes of the rapidly rising electricity prices in Australia in the decade to 2017 included excessive concentration of ownership arising from an imperfectly implemented privatisation process, combined with perverse regulatory incentives for wasteful grid investment, weak market misconduct laws and systemic complexity leading to poor consumer understanding of retail electricity pricing. Recent reforms are intended to address these market issues. The 2019 Prohibition of Electricity Market Misconduct (PEMM) laws are intended to ensure that reductions in electricity supply chain costs are passed on to consumers, that gentailers are not able to discriminate against smaller retailers in financial contracts markets, and that generators are not able to manipulate prices in wholesale spot markets. These laws are broadly formulated, and grant strong powers to the Australian Competition and Consumer Commission, including the power to apply to the Treasurer for a divestiture of assets order. State and Commonwealth default offers and retail price caps are intended to prevent excessive costs for customers on standing offers, and confusing and misleading offers labelled as discounts. Increasing solar and wind generation capacity is contributing to steadily reducing electricity costs and concentration of ownership. Despite continuing fossil fuel exploitation in Australia, renewable scale-up is likely further accelerate, for production of clean hydrogen to power low-emissions steel and aluminium production, manufacturing and resource processing. Until late 2021, renewable scale-up underpinned reducing wholesale prices, that were not fully reflected in retail prices. In early 2022, electricity wholesale price rises have been driven by surging coal prices, unplanned outages in aging coal plants, and transmission constraints limiting more widespread use of cheaper renewable power. In the event of future wholesale price declines achieved through increasing renewable penetration, the PEMM laws and default offers/price caps can play a useful role in ensuring cost reductions are passed on to consumers.     

Performance indices to measure and compare system utilization and congestion severity of different dispatch scenarios

In competitive electricity markets, energy Locational Marginal Prices (LMPs) are commonly used to allocate energy payments and transmission congestion charges and credits. In these markets, energy prices and transmission pricing are highly affected by transmission constraints, where a congested transmission is accompanied by congestion costs, lower system utilization, and higher energy prices due to resorting to out-of-merit order as expensive generating units are dispatched to alleviate congestion. The paper presents some performance indices to compare different dispatch options, where it proposes to use some congestion and system utilization measures. These measures are used in the paper to indicate level of system usage and congestion severity under different dispatch scenarios, and may enable the system operator or the qualified dispatch decision-making entity to decide which dispatch, among different dispatch scenarios, is the optimal. To show an example of using presented measures, planned line switching has been used to minimize transmission congestion cost and increase system utilization. The model used for energy market in the paper involves both spot (pool) transactions and firm bilateral contracts. The presented method is applied to a three-bus and an eight-bus test systems, where the results show that considering opening of some transmission lines may improve outcome of social-welfare problem, as reflected in reducing total congestion cost and improving system utilization.     

基于MOEA的智能电网需求侧管理分时电价优化方案

本文为降低分时电价方案中电力客户的用电成本并减少用电设备的平均延时,提出一种基于多目标进化算法的智能电网需求侧管理分时电价优化方案。首先简要介绍了分时电价方案及其优势;其次重点阐述了多目标进化算法评估用电成本和设备延时的具体实现方法,并给出了目标函数;最后,以Matlab/Simulink软件为平台对所提出的方法进行建模与仿真。结果表明,优化后的方案能显著降低用电成本并使用电设备正常运行的等待时间最小化。因此,对用户需求侧管理具有一定的参考意义。     

市场环境下分布式光伏协调售电交易机制及策略

推进分布式电源参与电力市场交易是能源发展与市场发展的必然要求,而分布式电源可通过售电公司代理的方式参与市场。在现货市场背景下,以分布式光伏为例,针对协调售电的模式,提出了以售电公司购电成本最小化为目标的交易决策模型。设计了代理双方“双价格”的合约定价机制,分别基于预测电价及实际电价确定优化决策价格和结算价格,前者用于模型优化,后者用于合约结算,从而实现代理双方的利益平衡,为售电公司代理并管理分布式光伏发电从而促进市场环境下分布式光伏的有效利用提供思路,也为售电公司在新的代理关系下参与现货市场申报提供依据。