Modification of boiler operating conditions for mercury emissions reductions in coal-fired utility boilers

Romero, Carlos E.; Li, Ying; Bilirgen, Harun; Sarunac, Nenad; Levy, Edward K.

doi:10.1016/j.fuel.2005.04.032

Cited by 51 publications

(29 citation statements)

References 5 publications

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“…The powdered carbon binds with Hg and PM in the flue gas and is subsequently captured by the PM reduction devices [12]. This method, however, would result in a significant increase in the cost of electricity from coal-fired power plants [3].…”

Section: Mercury Emissions Controlmentioning

confidence: 99%

“…Industrial, commercial, and institutional (ICI) boilers are one of the major sources of hazardous air pollutants (HAP), including mercury (Hg). Coal-fired electric power plants constitute the largest point source of unregulated Hg emissions in the United States [2][3][4]. It has been estimated that about forty-eight tons of Hg is emitted from coal-fired power plants in the United States annually, which is about one percent of the total world wide Hg emissions [5].…”

Section: Introductionmentioning

confidence: 99%

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Mercury Emissions Control from Existing Utility and Industrial Boilers

Fuller¹,

Khan²

2008

TOWMJ

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Industrial, commercial, and institutional (ICI) boilers are one of the major sources of hazardous air pollutants (HAP), including mercury (Hg). Coal-fired electric power plants constitute the largest point source of anthropogenic Hg in the United States. The primary objective of this paper was to address the mercury side of the boiler maximum achievable control technology (MACT) of the national emission standards for hazardous air pollutants (NESHAP). This paper analyzed data collected by a research team at West Virginia University (WVU) as part of a Mercury Emissions Research project. The research focused on solid fuel (coal) fired boilers covered by the industrial boilers MACT. Hg emissions data along with coal and stack analysis were collected through a combination of surveys and personal contact with appropriate individuals at these facilities. The collected data were analyzed to determine the applicability of Hg control technologies to ICI boilers and their emissions reduction capabilities.

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Section: Mercury Emissions Controlmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Mercury Emissions Control from Existing Utility and Industrial Boilers

Fuller¹,

Khan²

2008

TOWMJ

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“…However, the corresponding sorbent cost is very high. For example, for a 250MW unit emitting 65kg of Hg per year, it is estimated that it would cost between $1 million and $3 million to remove just 50% of the mercury present (Romero, 2005). Accordingly, many utilities are eagerly looking for more effective and less expensive technologies to control mercury emission.…”

Section: Introductionmentioning

confidence: 99%

The effects of carbon-in-ash on mercury capture from flue gas

Kim

2015

EMSD

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Mercury, although only a trace element in coal, is an important pollutant because coal burning is increasing around the world for manufacturing and energy production. In addition, coal-fired plants are the largest anthropogenic source of mercury emission to the environment. Mercury capture mostly occurs under heterogeneous conditions between sorbent particles and gaseous mercury, and this study is mainly devoted to understanding the role of carbon-in-ash on mercury capture from flue gas. Coal flyash samples are characterized by loss-on-ignition (LOI) carbon content, surface area (BET) tests, and scanning electron microscopy (SEM) morphology. Flyash sorbents are injected using an in-flight configuration and then mercury concentration is measured by Hg continuous emission monitoring system (CEMS). The unburned carbon in ash is found to be one main factor for capturing mercury. In addition, mercury capture increases when flyash samples have more surface area. Carbon in ash is also positively correlated with surface area within coal rank. This suggests that unburned carbon plays a formative or structural role in surface area increase on flyash. However, mercury uptake is shown to be relatively low when using flyash from high rank coal such as anthracite because of the small surface area coming from its non-porous structure. Therefore, when flyash is used as a sorbent for mercury capture, quantitative surface area should be compared and coal rank also should be considered. Carbon content in ash as mercury capture sorbents is Environmental Management and Sustainable Development ISSN 2164-7682 2015 a good indicator for mercury capture, but its surface area should also be considered for predicting mercury uptake.

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“…Mercury in coal-fired flue gas is often classified into three basic forms: elemental mercury (Hg 0 ), oxidized mercury (Hg 2+ ) and particulate-bound mercury (Hg p ) [6]. Hg 2+ is water-soluble, hence can be effectively captured in a wet flue gas desulfurization (WFGD) system.…”

Section: Introductionmentioning

confidence: 99%