燃气机组发电特性及其在电网中运行方式的研究

在全世界对节能减排和环境保护极其重视的情况下,对清洁、高效的燃气发电方式进行深入研究有重要意义。本文基于近几年我国华东地区安装的大容量新型S109FA联合循环机组的运行状况,对发电特性及其在电网中的运行方式进行分析研究,提出应该考虑不同类型燃气机组的特性,进行电厂规划设计和电网运行调度,以保证燃气机组在电网中充分发挥其优势。     

燃气─蒸汽联合循环的经济性与适应性

1 引言 燃气─蒸汽联合循环发电,由于其效率高、调峰性能好、安全可靠、环境污染小等一系列优点,是发电史上的一大突破,世界各国都在加快采用。美国能源部能源信息局曾预测,1990～2000年间,美国新增发电设备容量为100GW,其中燃气─蒸汽联合循环机组将占45GW。这就是说,新增发电设备容量的一半,将依靠大力开发联合循环机组,预示着联合循环发电将异军突起,取代蒸汽循环的主力军地位。尤其可望对原高中压燃煤蒸汽发电机组实施改造,加装前置燃气循环装     

考虑环境因素的燃气-蒸汽联合循环能耗特性分析

燃气-蒸汽联合循环机组具有较高的效率和环保特性,是发电领域的热点之一。联合循环的能耗特性会随环境条件和负荷条件变化而变化。考虑环境条件变化的燃气-蒸汽联合循环的机组变工况特性研究具有一定的理论意义和实用价值。分析研究燃气-蒸汽联合循环主要设备特性,采用差分进化法,结合某燃气-蒸汽联合循环6F发电机组的运行数据和设计数据对联合循环进行建模,挖掘出燃气-蒸汽联合循环中各参数之间的关系,进而得到燃气-蒸汽联合循环能耗随环境温度变化的规律,这对优化燃气-蒸汽联合循环性能具有重要意义。     

各种类型发电设备效率和装机成本的比较

发电设备类型效率功率万吐装机成本关元/吐0 0 .3一nl拓J 12门二现代大容量蒸汽发电机组现代中容量蒸汽发电机组磁流体发电装置(MHD)电气体发电装置(EGD)作基本负荷开式循环燃气轮机装置作基本负荷带回热器开式循环燃气轮机装置仅供尖峰负荷用喷水开式循环燃气轮机装置排气燃烧联合循环机组③排气加热联合循环机组②带燃气发生器的排气加热联合循环机组③增压锅炉联合循环机组④闭式循环燃气轮机装置热电子发电装置热离子发电装置燃料电池发电装置 39 3950~55⑤ 5020~2225~30 17 40 30 30 4225、30 10 10 60 1 10 125100~1501、3 100 3 3…     

燃气-蒸汽联合循环系统的能量分析及火用分析

燃气-蒸汽联合循环系统是利用燃气侧高温吸热和蒸汽侧低温放热来扩大循环平均吸放热温差,促进能源的梯级利用,以提高循环效率。简述了余热锅炉型燃气-蒸汽联合循环的工作原理,采用能量平衡分析联合循环机组的热效率及其影响因素,采用火用分析方法和具体算例分析联合循环机组各部位火用损失及大小。通过分析计算,寻求燃气-蒸汽联合循环发电系统能量利用的薄弱环节,并为联合循环的节能指明方向。     

洋浦电厂220MW燃气-蒸汽联合循环机组启动优化和安全运行因素分析

详细介绍了中海海南发电有限公司洋浦电厂220 MW燃气-蒸汽联合循环机组的启动过程,对联合循环机组启动过程中遇到的疑难问题进行了分析和探讨,从运行角度提出了可行的解决方案和优化措施,对于同类型机组的安全运行具有较好的借鉴意义。     

燃气蒸汽联合循环发电机组应用研究

近年来燃气发电特别是燃气蒸汽联合循环发电机组项目发展迅速,从机组热力学特性、配置选型、性能比较等方面进行了分析,并对其未来应用前景进行了展望。     

燃气轮机联合循环机组一次调频能力分析与优化方法研究

为实现燃气-蒸汽联合循环机组一次调频能力的分析与优化,构建了能够考虑燃气轮机、余热锅炉、汽轮发电机组等主设备出力调节速率限制因素,并且可以兼顾机组运行状态分析的通用燃气-蒸汽联合循环机组一次调频能力分析模型。对不同发电负荷下联合循环机组一次调频能力及其影响因素进行了分析,并提出了通过机组一次调频响应滞后时间补偿、实际转速不等率补偿两种方法来实现机组一次调频能力的优化。     

某采暖型2×75MW级联合循环分布式能源站机组选型及经济性分析

针对某采暖型2×75MW级燃气-蒸汽联合循环分布式能源站进行燃气轮机机组选型,在满足片区内冬季供暖的同时,进行适当发电。根据分布式能源站设计热负荷拟定5种装机选型方案。通过方案技术指标及经济性分析比选出3种方案,即2×6F.01、2×LM6000、2×SGT800。针对优选出的这3种方案,分别分析了气价和电价对方案经济性的影响。     

燃气-蒸汽联合循环机组运行指标动态管理的实现和应用

国内天然气发电行业得到了大力发展,但燃气-蒸汽联合循环机组指标管理体系还处于探索阶段,需要研究一种有效的管理手段,提高燃气轮机的运行管理水平。本文以浙江省某热电公司M701F4燃气轮机为例,依靠实时监测系统的数据提取分析功能,实现对燃气轮机指标的动态管理,对燃气-蒸汽联合循环机组发电运行指标管理具有一定的指导意义。     

Gas fired combined cycle plant in Singapore: energy use,GWP and cost—a life cycle approach

A life cycle assessment was performed to quantify the non-renewable (fossil) energy use and global warming potential (GWP) in electricity generation from a typical gas fired combined cycle power plant in Singapore. The cost of electricity generation was estimated using a life cycle cost analysis (LCCA) tool. The life cycle assessment (LCA) of a 367.5 MW gas fired combined cycle power plant operating in Singapore revealed that hidden processes consume about 8% additional energy in addition to the fuel embedded energy, and the hidden GWP is about 18%. The natural gas consumed during the operational phase accounted for 82% of the life cycle cost of electricity generation. An empirical relation between plant efficiency and life cycle energy use and GWP in addition to a scenario for electricity cost with varying gas prices and plant efficiency have been established.     

Economic comparison between coal-fired and liquefied natural gas combined cycle power plants considering carbon tax: Korean case

Economic growth is main cause of environmental pollution and has been identified as a big threat to sustainable development. Considering the enormous role of electricity in the national economy, it is essential to study the effect of environmental regulations on the electricity sector. This paper aims at making an economic analysis of Korea's power plant utilities by comparing electricity generation costs from coal-fired power plants and liquefied natural gas (LNG) combined cycle power plants with environmental consideration. In this study, the levelized generation cost method (LGCM) is used for comparing economic analysis of power plant utilities. Among the many pollutants discharged during electricity generation, this study principally deals with control costs related only to CO₂ and NO₂, since the control costs of SO₂ and total suspended particulates (TSP) are already included in the construction cost of utilities. The cost of generating electricity in a coal-fired power plant is compared with such cost in a LNG combined cycle power plant. Moreover, a sensitivity analysis with computer simulation is performed according to fuel price, interest rates and carbon tax. In each case, these results can help in deciding which utility is economically justified in the circumstances of environmental regulations.     

关于"燃气-蒸汽联合循环"几个技术经济问题的讨论

论述了我国燃气轮机的市场现状及发展前景,用实例展示联合循环的附加利益,在燃机单机的基础上进一步论述了气温气压对联合循环的影响作用,以及联合循环排放对环境的反影响.联合循环电厂的建设涉及的主要问题除燃气轮机外是燃料价格,如果发电用天然气价格太贵,可能成为燃机发展的主要障碍.     

Assessment of combined heat and power (CHP) integrated with wood-based ethanol production

A techno-economic assessment is made of wood-based production of ethanol, where the by-products are used for internal energy needs as well as for generation of electricity, district heat and pelletised fuel in different proportions for external use. Resulting ethanol production costs do not differ much between the options but a process where electricity generation is maximised by use of the solid residues as fuel for a combined cycle is found to give 20% more reduction of green-house gas emissions per liter of ethanol produced than the other options. Maximising electricity generation at the expense of district heat generation also allows more freedom when suitable sites for ethanol plants are looked for. Use of gasified biofuel for a combined cycle power plant is a demonstrated technology, however, the low ash and alkali content of the hydrolysis residue may allow direct combustion in the gas turbine topping cycle. This would reduce the necessary investment considerably. The potential advantages of using a combined cycle for maximising the electric power output from an energy combinate, producing ethanol and electricity from biomass, justifies further exploration of the possibilities for using hydrolysis residue directly as gas turbine fuel.     

The economic feasibility study of a 100-MW Power-to-Gas plant

Power-to-Gas (PtG) is a grid-scale energy storage technology by which electricity is converted into gas fuel as an energy carrier. PtG utilizes surplus renewable electricity to generate hydrogen from Solid-Oxide-Cell, and the hydrogen is then combined with CO₂ in the Sabatier process to produce the methane. The transportation of methane is mature and energy-efficient within the existing natural gas pipeline or town gas network. Additionally, it is ideal to make use of the reverse function of SOC, the Solid-Oxide-Fuel-Cell, to generate electricity when the grid is weak in power. This study estimated the cost of building a hypothetical 100-MW PtG power plant with energy storage and power generation capabilities. The emphasis is on the effects of SOC cost, fuel cost and capacity factor to the Levelized Cost of Energy of the PtG plant. The net present value of the plant is analyzed to estimate the lowest affordable contract price to secure a positive present value. Besides, the plant payback period and CO₂ emission are estimated.     

Exergoeconomic machine-learning method of integrating a thermochemical Cu–Cl cycle in a multigeneration combined cycle gas turbine for hydrogen production

Integrating new technologies into existing thermal energy systems enables multigenerational production of energy sources with high efficiency. The advantages of multigenerational energy production are reflected in the rapid responsiveness of the adaptation of energy source production to current market conditions. To further increase the useful efficiency of multigeneration energy sources production, we developed an exergoeconomic machine-learning model of the integration of the hydrogen thermochemical Cu–Cl cycle into an existing gas-steam power plant. The hydrogen produced will be stored in tanks and consumed when the market price is favourable. The results of the exergoeconomic machine-learning model show that the production and use of hydrogen, in combination with fuel cells, are expedient for the provision of tertiary services in the electricity system. In the event of a breakdown of the electricity system, hydrogen and fuel cells could be used to produce electricity for use by the thermal power plant. The advantages of own or independent production of electricity are primarily reflected in the start-up of a gas-steam power plant, as it is not possible to start a gas turbine without external electricity. The exergy analysis is also in favour of this, as the integration of the hydrogen thermochemical Cu–Cl cycle into the existing gas-steam power plant increases the exergy efficiency of the process.     

A review on the pattern of electricity generation and emission in Iran from 1967 to 2008

The electricity consumption growth in Iran requires a rapid development of power plant construction. Like many other countries, most of the power plants in Iran are using fossil fuel. In the past decade, thermal power plants generated about 94% of electricity and about 6% was generated by renewable sources such as hydro-power. This study is to show a clear view of 42 years an evolutionary trend of Iran's electricity generation industry. The capacity of power generation installed and electricity generation from the years 1967 to 2008 has been gathered. The total pollutant emissions and emission per unit electricity generation for each type of power plants have also been calculated using emission factors and the pattern of electricity generation and emission has been presented. The results shown that encouraging of using renewable energy sources and increasing the contribution of the combined cycle as a best type of thermal power plants and use more natural gas is recommended to reduce emission.     

计入峰谷分时上网电价的天然气发电竞争力分析

针对当前天然气发电燃料成本高、天然气供应不足而导致上网电价水平偏高,难以与煤电竞价的问题,提出考虑在发电侧实施峰谷分时上网电价机制,鼓励燃气电厂提高峰时段的上网电量,同时制定计入峰谷分时电价补贴标准来提高天然气发电的市场竞争力。算例结果表明,该措施明显提高了天然气发电的经济优势、气价的承受能力、与煤电平等竞价上网的竟争力。     

Aspen Plus simulation of biomass integrated gasification combined cycle systems at corn ethanol plants

Biomass integrated gasification combined cycle (BIGCC) systems and natural gas combined cycle (NGCC) systems are employed to provide heat and electricity to a 0.19 hm³ y⁻¹ (50 million gallon per year) corn ethanol plant using different fuels (syrup and corn stover, corn stover alone, and natural gas). Aspen Plus simulations of BIGCC/NGCC systems are performed to study effects of different fuels, gas turbine compression pressure, dryers (steam tube or superheated steam) for biomass fuels and ethanol co-products, and steam tube dryer exhaust treatment methods. The goal is to maximize electricity generation while meeting process heat needs of the plant. At fuel input rates of 110 MW, BIGCC systems with steam tube dryers provide 20–25 MW of power to the grid with system thermal efficiencies (net power generated plus process heat rate divided by fuel input rate) of 69–74%. NGCC systems with steam tube dryers provide 26–30 MW of power to the grid with system thermal efficiencies of 74–78%. BIGCC systems with superheated steam dryers provide 20–22 MW of power to the grid with system thermal efficiencies of 53–56%. The life-cycle greenhouse gas (GHG) emission reduction for conventional corn ethanol compared to gasoline is 39% for process heat with natural gas (grid electricity), 117% for BIGCC with syrup and corn stover fuel, 124% for BIGCC with corn stover fuel, and 93% for NGCC with natural gas fuel. These GHG emission estimates do not include indirect land use change effects.     

Life cycle assessment of an alkaline fuel cell CHP system

A life cycle assessment (LCA) of an alkaline fuel cell based domestic combined heat and power (CHP) system is presented. Literature on non-noble, monopolar cell design and stack construction was reviewed, and used to produce a life cycle inventory for the construction of a 1 kW stack. Inventories for the ancillary components of other commercial fuel cell products were consulted, and combined with information on the fuel processing requirements of alkaline cells to suggest a hypothetical balance of plant that would be required to produce AC electricity and domestic grade heat from natural gas and air.