湿法烟气脱硫工艺中烟气再热方式的选择

分析了湿法烟气脱硫烟气再热原因，介绍了多种烟气再热方法，并对其进行了技术分析，为湿法烟气脱硫工程的烟气再热系统设计提供了依据。     

湿法烟气脱硫工艺中烟气再热方式的选择

分析了湿法烟气脱硫烟气再热原因,介绍了多种烟气再热方法,并对其进行了技术分析,为湿法烟气脱硫工程的烟气再热系统设计提供了依据。     

半干半湿法烟气脱硫装置中喷雾增湿技术的研究

脱硫塔内喷雾增湿技术是影响燃煤锅炉半干半湿法烟气脱硫效果的一个重要环节。分析了供水量和压力的变化关系，通过对脱硫装置喷雾增湿技术的优化，实现对增湿系统高压水的压强的精确调节，控制脱硫塔内雾滴的颗粒直径在80μm左右，从而达到理想的增湿效果。     

半干半湿法烟气脱硫技术的工业应用研究

探讨了日本半干半湿法脱硫除尘系统和中国环境科学研究院半干半湿法烟气脱硫除尘示范系统的主要差别 ,研究了半干半湿法烟气脱硫技术在出塔烟气温度、钙硫摩尔比和循环粉煤灰返灰等方面对脱硫效率的影响。结果表明 ,在脱硫塔出口烟气温度为 78℃、m(循环粉煤灰返灰 )∶ m(石灰 )为 1∶ 4、n( Ca)∶ n( S) <1.2时 ,脱硫效率达 85 .1%;在 n( Ca)∶ n( S) =1.4时 ,脱硫效率可达 88.3 %。     

半干半湿法脱硫灰循环利用中试试验研究

半干半湿法脱硫产生的脱硫灰中混有大量有效钙和粉煤灰，本文对其进行了循环利用机理分析及试验研究，证实脱硫灰循环大大提高了钙的利用率，降低了钙硫比，但循环倍率增加到2倍以上时，脱硫效率增速变缓。脱硫灰的循环利用对降低脱硫运行费用是非常有效的。     

某脱硫添加剂在600MW机组湿法烟气脱硫系统中的应用研究

国内对于脱硫添加剂在石灰石-石膏湿法烟气脱硫系统中应用研究大多停留在实验室及小型脱硫系统中,对大型火电机组石灰石-石膏湿法烟气脱硫系统中的应用研究还不够深入.详细论述了某脱硫添加剂在600 MW机组上的应用情况,研究该脱硫添加剂加入后对脱硫系统效率的提升作用及对脱硫石膏和脱硫废水的影响,为大型火电机组石灰石-石膏湿法烟...     

燃煤电站湿法烟气脱硫的颗粒物脱除效果

伴随着我国燃煤电站污染物严峻形势,湿法烟气脱硫协同捕集颗粒物越来越受到工程应用部门的重视。从基本理论出发,引入捕集体与颗粒碰撞、拦截与扩散的基本方程,推导并建立多液滴对多颗粒的捕集模型。研究结果表明：直径245 μm的液滴,沉降速度小于气流速度,会被携带出脱硫塔;液滴对PM0.1、PM1、PM2.5、PM5、PM10颗粒物的去除效率为U型曲线,910 μm液滴对颗粒物的去除效率比4 666 μm液滴高近百倍;同等质量浓度,不同粒度分布,脱硫塔除尘性能仍然差异较大。     

半干半湿法烟气脱硫装置中喷雾增湿技术的研究

脱硫塔内喷雾增湿技术是影响燃煤锅炉半干半湿法烟气脱硫效果的一个重要环节。分析了供水量和压力的变化关系 ,通过对脱硫装置喷雾增湿技术的优化 ,实现对增湿系统高压水的压强的精确调节 ,控制脱硫塔内雾滴的颗粒直径在 80 μm左右 ,从而达到理想的增湿效果     

氧化镁湿法烟气脱硫回收工艺的技术经济可行性初步分析

介绍了回收结晶硫酸镁的氧化镁湿法烟气脱硫工艺的基本工艺流程，在抛弃法脱硫系统上所作的工业试验证明了吸收液循环提浓MgSO4的可行性。参照工业硫酸镁生产工艺对130t／h燃煤锅炉烟气脱硫作了回收工艺的投资效益分析和整体工艺的经济性评价，结果表明回收工业硫酸镁具有良好的经济效益。     

湿式氧化镁烟气脱硫技术及应用

介绍了氧化镁湿法烟气脱硫工艺的基本原理、工艺流程、工艺特点及副产物处理方法,分析了该工艺在我国的应用前景.     

Status and Problems of Regenerable Flue Gas Desulfurization Processes

Fourteen sulfur and/or sulfuric acid producing regenerate FGD processes were discussed at the 1974 FGD Symposium in Atlanta. During the period elapsed since then, considerable status change has occurred on many of these regenerable processes. Other regenerable processes which were not as well known during 1974 have surfaced in 1975. The problems of obtaining reducing gases (hydrogen sulfide, carbon monoxide, and hydrogen) for the reduction of sulfur dioxide product streams to elemental sulfur have become severe due to shortages of natural gas or other petroleum based feedstock. A new sulfur producing process which employs CO and H₂ directly (rather than the H₂S required for liquid and vapor base Claus reactions) is gaining attention. This paper discusses briefly: (1) the announced status of the many regenerable FGD processes, (2) the problem of reductant gas supply, and (3) the effect on FGD processes of using coal based reducing gas instead of reformed natural gas.     

Use of Seawater in Flue Gas Desulfurization

For seasite power plants using seawater for condenser cooling, Bechtel developed a new process to remove better than 90 percent of flue gas SO₂ using seawater and lime. Tests demonstrate that marine life is not affected by the effluent from this unique scrubbing process; therefore, the aqueous effluent containing reacted products (gypsum) in solution at low concentration is suitable for discharge to the sea.     

喷射鼓泡法烟气脱硫工艺

对以喷射鼓泡反应器为主设备，石灰石浆液为脱硫剂的湿法烟气脱硫工艺进行了实验研究，结果表明主要参数[烟气压降Δp、ф（液气）比、吸收液pH值、进气SO2浓度]对脱硫效率均有较大的影响。     

Modeling of Dry Injection Flue Gas Desulfurization

Dry processes for controlling sulfur dioxide emissions by injecting sodium based sorbents in the ductwork ahead of a bag filter are effective and more simple alternatives to conventional FGD processes. This paper presents a fundamental kinetic model of the dry injection process. Experimental data from pilot scale tests are reported. The model is shown to be applicable to the dry injection process. However, further experimental work is recommended to get a better understanding of the reaction mechanisms.     

循环流化床烟气脱硫技术及其经济分析

简要介绍了循环流化床烟气脱硫技术及国内外研发现状，通过对不同容量机组锅炉采用循环流化床工艺和其它工艺烟气脱硫方案的分析计算，给出并讨论了各种方案的总投资、年运行费、单位运行费及均化脱硫成本等的经济技术指标。     

Resource Recovery from Flue Gas Desulfurization Systems

The cost effective benefits of yielding a flue gas desulfurization (FGD) sludge predominantly composed of CaSO₄·2H₂O, have been previously established. The recovery of this material as FGD by-product gypsum has been demonstrated abroad. Recently U.S. wallboard manufacturers have recognized the viability of this recovery practice. Such techno-economic decision making variables as a) by-product specification, b) transportation costs, and c) location of suitable FGD systems enable the recognition of FGD by-product recovery. Recent investigations of resultant solids content and chloride washing reflect the technical possibility of delivering a suitable product. Commercial and economic factors favor recovery based upon rising disposal and transportation costs. Existing and near term proposed systems surface the technical and commercial problems faced by utilities considering recovery.

Generation of an oxidized FGD sludge consisting of 90⁺% CaSO₄·2H₂O and dewatered to 80⁺% solids is technically achievable by air sparging within the FGD system. Although the product is suitable for land disposal, electric power utilities should consider and evaluate by-product recovery. U.S. wallboard manufacturers have established technical criteria for FGD by-product gypsum. Percent CaSO₄·2H₂O, final solids content, particle size, and chloride content are primarily technical parameters. Technology exists within the FGD industry to satisfy these criteria and results are discussed.

Economic factors comparing mining costs, transportation costs, and disposal costs are developed for specific utility projects. Such comparison established generalized financial criteria for a given utility to develop the economic reasonableness of considering FGD byproduct recovery.

End product user perspectives are presented providing electric utilities with a realistic appreciation for by-product recovery potential. Location of existing wallboard plants highlight potential recovery regions. Quality control problems are discussed in terms of generating a by-product rather than a disposable material.     

Flue Gas Desulfurization: The State of the Art

ABSTRACT

Coal-fired electricity-generating plants may use SO₂ scrubbers to meet the requirements of Phase II of the Acid Rain SO₂ Reduction Program. Additionally, the use of scrubbers can result in reduction of Hg and other emissions from combustion sources. It is timely, therefore, to examine the current status of SO₂ scrubbing technologies. This paper presents a comprehensive review of the state of the art in flue gas desulfurization (FGD) technologies for coal-fired boilers.

Data on worldwide FGD applications reveal that wet FGD technologies, and specifically wet limestone FGD, have been predominantly selected over other FGD technologies. However, lime spray drying (LSD) is being used at the majority of the plants employing dry FGD technologies. Additional review of the U.S. FGD technology applications that began operation in 1991 through 1995 reveals that FGD processes of choice recently in the United States have been wet limestone FGD, magnesium-enhanced lime (MEL), and LSD. Further, of the wet limestone processes, limestone forced oxidation (LSFO) has been used most often in recent applications.

The SO₂ removal performance of scrubbers has been reviewed. Data reflect that most wet limestone and LSD installations appear to be capable of ~90% SO₂ removal. Advanced, state-of-the-art wet scrubbers can provide SO₂ removal in excess of 95%.

Costs associated with state-of-the-art applications of LSFO, MEL, and LSD technologies have been analyzed with appropriate cost models. Analyses indicate that the capital cost of an LSD system is lower than those of same capacity LSFO and MEL systems, reflective of the relatively less complex hardware used in LSD. Analyses also reflect that, based on total annualized cost and SO₂ removal requirements: (1) plants up to ~250 MW_e in size and firing low- to medium-sulfur coals (i.e., coals with a sulfur content of 2% or lower) may use LSD; and (2) plants larger than 250 MW_e and firing medium- to high-sulfur coals (i.e., coals with a sulfur content of 2% or higher) may use either LSFO or MEL.     

Alabama Electric Cooperative Flue Gas Desulfurization Operating and Maintenance Experience

Alabama Electric Cooperative, Leroy, AL, has recently started up two 255 MW units, including a flue gas desulfurization system, at their Tomblgbee Station. The flue gas desulfurization system was designed by Peabody Process Systems, Inc., Stamford, CT. After 20 months operation, performance, in terms of start-up operations and maintenance, has been exceptionally good. This paper discusses those design factors which contributed to this successful performance.     

A History Of Flue Gas Desulfurization Systems Since 1850

Methods for removing sulfur dioxide (SO2) from boiler and furnace exhaust gases have been studied throughout the twentieth century. Early concepts useful for flue gas desulfurization (FGD) appear to have germinated in England circa 1850. The research during this period was motivated primarily by the quest to uncover the fundamental physical properties of substances.