湖南沅水流域梯级水库联合优化调度研究

根据沅水各断面历史水文资料及湖南当前丰枯电价水平,运用动态规划优化理论归纳了沅水流域梯级电站联合运行规律,提出了调节能力较强的三板溪、五强溪两个水库的运行方式.实例结果表明,该方式对沅水流域水库联合调度、充分发挥流域梯级发电效益具有指导意义.     

流域龙头水库超常规调度与补偿效益分析

提出了供水期适当加大多年调节水库特别是流域龙头水库的消落水位、充分发挥流域梯级电站调峰效益的超常规调度思路,建立了超常规调度模型,并结合沅水流域三板溪及下游梯级电站的实况进行分析。结果表明,该模型可以产生较大的发电效益和社会效益。最后还分析了三板溪对下游梯级电站的补偿效益。     

沅水流域梯级电站发电优化调度决策支持系统

介绍了沅水流域梯级电站发电优化调度决策支持系统的开发目标、模式及开发原则,提出了结构合理、设计先进、功能齐全、实用性和可扩展性强的功能结构,成功地解决了沅水流域梯级电站发电调度问题,为沅水梯级电站发电优化调度提供了决策支持。     

考虑反调节水库作用的木里河梯级水电站水库中长期优化调度研究

木里河是雅砻江中游最大支流,目前已形成两库四级梯级水电站群,充分利用梯级末端立洲水库的反调节能力,将有效提升流域整体发电效益。为分析梯级水电最优运行方式,以流域梯级枯期最小出力最大和梯级年发电量最大为目标函数,建立了木里河流域两库四级的优化调度模型,并采用逐渐优化算法(POA)求解,最大化利用末端水库反调节能力。结果表明,通过立洲水库的反调节作用,木里河流域梯级枯水期的可靠出力得到有效改善,发电效益得到有效提升。     

金沙江下游梯级与三峡梯级水库联合发电调度

针对金沙江下游梯级水库的相继建成将会改变长江流域梯级水库综合调度格局问题,构建了金沙江下游梯级水库与三峡梯级水库联合发电调度模型,并采用逐次优化算法进行了求解.结果表明,采用联合优化调度后整个梯级发电效益明显,与原设计方案相比梯级平均发电量可增加6.29;与各梯级单独优化运行相比,梯级发电量可增加1.48%.     

小浪底-西霞院梯级电站调峰能力研究

针对小浪底-西霞院梯级电站短期调峰调度亟待解决的问题,基于小浪底水力发电厂实际运行情况,制定了两库联合调度优化运行方案并进行了计算和分析,同时采用两电站梯级水库联合优化调度系统软件验证了优化方案的可行性,提出了在电网谷段充分利用西霞院水库的反调节库容以降低小浪底的日均出库流量和耗水率以提高两库峰谷比的运行方式.     

多级协同模式下华中电网大规模水电站群跨网调峰调度研究

根据华中区域大规模电站群跨省电力输送运行实际,针对水电站群优化调度需兼顾多电网调峰需求、电站出力计划编制复杂问题,提出了一种多级协同模式(MLCM)下大规模水电站群跨网调峰调度方法。以各受端省级电网余荷均方差最小为目标建立电站群联合跨网调峰调度模型,通过流域梯级电站群层级排序获得电站优化次序,简化电站间复杂耦合关系,将约束处理耦合至电站出力网间二次分配过程中,逐步迭代调整各受电网受电计划,获得满足多电网调峰需求的电站出力计划与电网受电过程。所提方法通过华中区域三葛梯级、清江梯级、沅水梯级水电站群调度模拟得到验证,应用结果显示电站出力计划在兼顾多电网调峰需求的同时充分发挥了水电站群联合调峰容量效益,具有工程实用价值。     

乌溪江梯级水电站隐随机优化调度方案

针对乌溪江梯级水电站的特点,充分利用水库优化调度技术,采用隐随机方法分别拟合了该梯级电站逐月和逐旬的优化调度函数,并通过模拟调度对比分析,最终确定了该梯级电站的优化调度方案。计算表明,该优化成果合理,效益显著,能有效应用于生产实际。     

溪洛渡—向家坝梯级AGC的工程实现

随着金沙江溪洛渡、向家坝水电站的投产发电,梯级自动发电控制(AGC)在实现溪洛渡—向家坝梯级优化调度和精益运行等方面的重要性也越来越突出,本文从溪洛渡—向家坝梯级AGC的控制方式和目标入手,详细介绍了梯级AGC的控制模式、运行方式、优化控制以及安全闭锁策略等,并对现场调试情况进行了分析介绍,说明了其在梯级负荷优化分配和电站高效、稳定运行中的重要作用,也为今后流域梯级AGC的设计与实现提供了借鉴。     

雅砻江下游梯级水库隐随机联合优化调度函数研究

针对不确定来水梯级水库优化调度问题,基于隐随机调度函数基本原理,以长系列优化调度结果为依据,建立多元线性回归模型、门限回归模型和BP人工神经网络模型模拟雅砻江下游梯级水库联合调度过程,综合对比各调度函数模拟效果,且与确定来水的优化调度结果做了对比。结果表明,门限回归模型和BP神经网络模型调度函数均能较好地模拟梯级水库运行,可指导梯级电站调度运行。     

基于总保证出力协调的梯级水库联合调度图研究

针对具有龙头调节的多个季调节性能及以上水库构成的串联梯级水电站的联合调度问题,借鉴单库水库调度图制作思想,基于梯级总保证出力协调原则,提出了梯级水库联合调度图制定的基本原理,以梯级总电量最大化为目标探讨了梯级水库联合调度图的优化方法,并以沅水为例研究了梯级联合调度图。结果表明,该方法在梯级水头及水量充分利用、梯级相互补偿等方面作用显著,对提高梯级水电站的年均发电量和梯级总保证出力成效突出。     

金沙江下游梯级汛前联合消落控制方式研究

流域梯级水库群汛前消落控制是水库调度的关键问题之一,而传统的判别系数法在确定水库群消落次序时未考虑弃水风险的存在,难以满足实际消落控制需求。为此,以金沙江下游梯级枢纽为例,构建了梯级水库汛前消落控制模型,针对不同典型来水并通过设定梯级各水库不同消落时机代入模型进行模拟调度,得到了梯级不同时机组合所对应的发电量和弃水量,从中推求出不同来水情景下兼顾发电和弃水的梯级水库最优消落时机。结果表明,确定的梯级消落控制方法能很好地适应不同的调度需求,可为金沙江下游梯级水库消落调度工程应用提供指导。     

沅水流域径流周期性规律分析

根据滤波相关理论对沅水流域径流序列的突变性、跳跃性和趋势性进行了分析,并根据熵谱图法原理提出了寻求径流系列近似周期及检验方法,以沅水流域近81 a径流序列资料为例,分析了周期性规律,得出了对序列影响最大的周期分别为16.7、5 a的结论.研究结果对沅水流域水库联合调度和水资源利用具有较强的指导意义.     

The potential of demand-side management in energy-intensive industries for electricity markets in Germany

This paper investigates the technical and economic potential of energy-intensive industries to provide demand-side management (DSM) in electricity and balancing markets through 2030. Increasing shares of renewables will lead to a rising demand for ancillary services at the same time that less conventional plants will be available to provide these services. This paper makes projections on the extent to which DSM from industrial processes can provide economic benefits in electricity markets with renewables by providing tertiary reserve capacity. Different industrial processes and their specific technical and economic properties are investigated and compared with other storage devices and electricity generation technologies. Based on an extension of an existing European electricity market model, simulations are used here to make long-term forecasts for market prices, dispatch and investments in the electricity markets through linear optimization.     

四川省鸭嘴河梯级水电规划开发格局探讨

主要论述在确定鸭嘴河梯级水电开发格局中,如何利用河流形态及资源分布特点,通过控制性水库设置位置,梯级开发方式与衔接,近期与远期,资源利用与补偿效益,水库淹没及移民安置,工程技术难度等方面对梯级开发方案的影响评价分析,为具有设置多年调节性能的“龙头”水库河流梯级规划与适应电力市场发展提供有益的思考方法。     

A comparison of variation management strategies for wind power integration in different electricity system contexts

Variation management strategies improve the capability of the electricity system to meet variations both in the electricity demand and in the generation that relies on variable energy sources. In this work, we introduce a new, functionality‐based, categorization of variation management strategies: shifting (eg, batteries), absorbing (eg, power‐to‐gas), and complementing (dispatchable generation, including reservoir hydropower) strategies. A dispatch model with European coverage (EU‐27 plus Norway and Switzerland) is applied to compare the benefits of shifting and absorbing strategies on wind integration in regions with different amounts of complementing strategies in place. The benefits are measured in terms of the wind value factor, wind owner revenue, and average short‐term generation cost. The results of the modeling show that the reduction in average short‐term generation cost and the increase in revenue earned by the wind owner from shifting strategies, such as the use of batteries, are more substantial at low wind shares than at high wind shares. The opposite situation is found for absorbing strategies, such as power‐to‐gas, which are found to be more efficient at reducing the average generation cost and increasing profit for the wind owner as the wind share increases. In regions that have access to complementing strategies in the form of reservoir hydropower, variation management has a weak ability to reduce the average short‐term generation cost, although it can increase significantly the revenue accrued by the wind power owner.     

基于SQP法的电厂日前合约市场报价策略研究

在电力市场环境下,发电企业为了追求经济效益的最大化,必须在优化机组负荷分配的基础上掌握企业运行成本,并在电力市场上报出具有竞争力的上网电价。针对日前市场的特殊性,并建立了机组经济性曲线拟合的数学模型和基于序列二次规划法(SQP法)的机组负荷优化分配模型,指出了完全成本加成法的报价方法。用算例验证了一个发电企业在4个时段日前市场负荷的耗量成本。     

The impact of the North Atlantic Oscillation on electricity markets: A case study on Ireland

The North Atlantic Oscillation (NAO) is a large-scale atmospheric circulation pattern driving climate variability in north-western Europe. As the deployment of wind-powered generation expands on electricity networks across Europe, the impacts of the NAO on the electricity system will be amplified. This study assesses the impact of the NAO, via wind-power generation, on the electricity market considering thermal generation costs, wholesale electricity prices and wind generation subsidies. A Monte Carlo approach is used to model NAO phases and generate hourly wind speed time-series data, electricity demand and fuel input data. A least-cost unit commitment and economic dispatch model is used to simulate an island electricity system, modelled on the all-island Irish electricity system. The impact of the NAO obviously depends on the level of wind capacity within an electricity system. Our results indicate that on average a switch from negative to positive NAO phase can reduce thermal generation costs by up to 8%, reduce wholesale electricity prices by as much as €1.5/MWh, and increase wind power generators' revenue by 12%.