Coal-fueled Power Research Articles

‘Switch off Hazelwood’: Policing, Protest and a ‘Polluting Dinosaur’

Traditionally, the policing of protest has been a vexed and problematic issue. The contemporary policing of climate change protests and camps challenges police capability both to facilitate such protests and to maintain control and order. The case study of the policing of the September 2009 protest against the Hazelwood coal-fuelled power station in the Latrobe Valley presents a microcosm of the dilemmas faced by both police and protesters in negotiating effective and peaceful protest. The eclectic and disparate nature of the climate change protests based on affinity groups affronts the police bureaucratic structure. This article argues that police–protester dialogue and negotiation, although limited by traditional suspicions, polarised organisational structures and diverse mindsets, are vital for the successful facilitation of peaceful protest, especially in relation to ongoing climate change dissent against coal-fired power plants.

Carbonate Fuel Cell Application for Synergistic Power Generation and Carbon Dioxide Capture

FuelCell Energy, Inc. (FCE) has developed novel system concepts for separation of carbon dioxide from greenhouse gas emission sources, using Direct FuelCell® (DFC®) technology. DFC is based on carbonate fuel cells featuring internal reforming. The unique chemistry of carbonate fuel cells offers an innovative approach for separation of CO2 from fossil-fuel power plant exhaust streams (flue gases). DFC-based CO2 separation systems are suitable for many types of coal-based power plants, from existing pulverized coal (PC) plants to future integrated gasification combined cycle (IGCC) plants. The carbonate fuel cell system also produces electric power at high efficiency. Cost of electricity (COE) analysis of the DFC system suggests that the simultaneous generation of power and CO2 capture is an attractive scenario for re-powering the existing coal-fueled power plants.

ウメ、カキ剪定枝によるバイオ固体燃料の圧縮強度特性

In order to reduce the exhaustion of carbon dioxide, the utilization of unused woody biomass such as forestry biomass and pruned branch has come to attract attention as an alternative fuel of coal. Most of the coal are used at coal-fueled power plants and iron mills. In the present study, bio-solid fuels to alternate coal cokes are investigated. Pruned branches of ume and persimmon which are the typical fruit trees cultivated in Wakayama prefecture are used as biomass resources. To establish a technical basis for the method of manufacturing bio-solid fuel with high hardness, effects of molding temperature, tress species and diameter of pruned branch on compressive strength properties of bio-solid fuel are clarified. The results obtained are as follows. In the case of ume, the compressive strength has a maximum, when the molding temperature is 140-160 degree C. There is no effect of diameter of pruned branch on compressive strength. In the case of persimmon, the compressive strength has a maximum, when the molding temperature is 180 degree C. The compressive strength decreases with decreasing the diameter of pruned branch. The difference in compressive strength between ume and persimmon is considered to be caused by the particle shape.

Carbon Sequestration Systems Using Direct FuelCell for Combined Carbon Dioxide Separation and Power Generation

FuelCell Energy (FCE) has developed novel system concepts for separation of carbon dioxide from greenhouse gas emission sources, using Direct FuelCell® (DFC®) technology. DFC is based on carbonate fuel cells featuring internal reforming. The unique chemistry of carbonate fuel cells offers an innovative approach for separation of CO2 from fossil-fuel power plant exhaust streams (flue gasses). DFC-based CO2 separation systems are suitable for many types of coal-based power plants, from existing pulverized coal (PC) plants to future integrated gasification combined cycle (IGCC) plants. The carbonate fuel cell system also produces electric power at high efficiency. Cost of electricity (COE) analysis of the DFC system suggests that the simultaneous generation of power and CO2 capture is an attractive scenario for re-powering the existing coal-fueled power plants.

Characterization and quantification of persistent organic pollutants in fly ash from coal fueled thermal power stations in India

The burning of pulverized coal to produce energy for generation of electricity in thermal power plants results in huge quantity of coal ash of varying properties. In India the coal based thermal power plants have been the major source of power generation in the past and would continue for decades to come. Because of the increase in electricity production, the amount of ash produced will increase proportionally. Very few studies on characterization of organic constituents in fly ash from Indian thermal power plants have been reported in the literature. In the present study, the fly ashes generated from five thermal power stations from different parts of India were investigated regarding the elaboration of distribution pattern of persistent organic pollutants (POPs) such as PAHs and PCBs in them. The PAHs in the fly ash samples were identified and quantified using high pressure liquid chromatography (HPLC-UV) whereas the estimation of PCB congeners was carried out using gas chromatography (GC-ECD). Lower molecular weight (MW) PAHs, were found to be predominant in fly ash samples. The concentration of Benzo(a)Pyrene which is the most potent carcinogenic PAH, varied between 0.82 ng/g and 18.14 ng/g with a mean concentration of 9.02 ng/g. Among the PCB congeners, CB-77 is having higher toxicity value, the concentrations of which in the fly ash samples were in the range of 4.58 ng/g to 104.98 ng/g with a mean value of 62.53 ng/g.

Storing CO2 with enhanced oil recovery

Abstract CO2 enhanced oil recovery (CO2-EOR) offers the potential for storing significant volumes of carbon dioxide emissions while increasing domestic oil production. This presentation, based on a recently completed study for DOE/NETL, examines the domestic oil resource amenable to CO2-EOR, the size of the related market for CO2, and the benefits to the power sector from CO2 sales to the EOR industry. The study finds that, depending on future oil prices and the costs for purchasing CO2 from power plants and other industrial sources, from 39 to 48 billion barrels of oil could be economically recoverable with CO2-EOR. In addition, the size of the market for CO2 offered by the EOR industry is on the order of 7,500 million metric tons between now and 2030. With advances in CO2-EOR and storage technology, the economically recoverable oil resource would increase to 54 to 70 billion barrels. The market for CO2 from the EOR industry is examined in depth from the coal-fueled power plant industry’s standpoint. The sale of CO2 emissions captured from new coal-fueled power plants could provide significant revenue offsets to the cost of installing carbon capture technology. It is estimated these revenue offsets along with a value for carbon abatement could enable 40% (48 out of 121 GW) of the new coal-fueled power capacity expected to be built between now and 2030 to install CCS. With advances in CO2-EOR and storage technology the number of power plants with CCS could increase to 50 to 70 GWs. This would provide significant assistance toward addressing CO2 emissions from this sector, helping drive down the costs of installing CCS technology.

Modelling of chemical fractionation patterns of metals in soils by two-way and three-way principal component analysis

The ‘pseudo-total’ contents and the chemical fractionation pattern of eight toxic elements (As, Cd, Co, Cu, Cr, Ni, Pb and Zn) have been determined in 12 soil samples collected around a coal-fuelled power plant (Velilla del Río Carrión, Spain) by using, respectively, the US-EPA 3051 norm and the modified BCR (SM&T) chemical fractionation procedure. The ‘pseudo-total’ dataset has been analyzed by classical two-way principal component analysis (PCA) finding a PC accounting for the metal ‘pollution’ of the area. On the other hand, the three-dimensional (samples × metals × fractions) X array obtained after application of the modified BCR SM&T procedure, has been studied by matrix augmentation (MA-PCA) and three-way principal component analysis (3-PCA) using PARAFAC and TUCKER3 models. Whereas both MA-PCA and PARAFAC originated two-factor models biased towards the different chemical fractionation of the samples, the best TUCKER3 model [1, 2, 2] takes into account simultaneously both the ‘pseudo-total’ contents and the chemical fractionation of the soil samples. Therefore, the TUCKER3 originated a better representation of the global environmental impact caused by the power plant, and the plotting of the soil samples loadings, A1, in the physical space allowed to locate the most potentially hazardous areas.

Availability of logging residues and potential for electricity production and carbon displacement in the USA

Abstract This study assessed the abundance and regional distribution of logging residues and their potential for electricity generation and CO 2 emission displacement in the USA. Based on the 1997 Forest Inventory and Analysis (FIA) data, a 70% residue recovery rate, and a minimum viable power plant capacity of 10 MW, annually recoverable logging residues in the USA were estimated at 13.9 million dry t from growing stock and 36.2 million dry t from both growing stock and other sources. Most logging residues were located in the eastern USA; the Southeast and South Central regions accounted for approximately two-thirds of the national total from growing stock and about 50% of that from both growing stock and other sources. The recoverable residues from both growing stock and other sources could generate 67.5 TWh electricity annually. This would displace 17.6 million t carbon emitted from coal-fueled power plants (about 3% of total carbon emissions from the US electricity sector in 1997) at a cost ranging from US$60 to 80 t −1 C.

Prospects for co-firing of clean coal and creosote-treated waste wood at small-scale power stations

If a small-scale clean coal fueled power plant is co-fueled with 5% of creosote-treated used-up sleeper wood, the decontamination by carbonisation at 500 ?C in an indirectly heated rotary kiln with the diameter 1.7 m and effective length 10 m can be realized. It should be included in the "3R Clean Coal Carbonisation Plant" system, which processes coal. It will improve the heat balance of the system, since the carbonisation of wood will deliver a lot of high caloricity pyroligneous vapour to the joint furnace of the "3R Clean Coal Carbonisation Plant". Pine wood sleeper sapwood contains 0.25% of sulphur, but the average pine sleeper wood (sapwood and heartwood) 0.05% of sulphur. Most of the sulphur is lost with the pyroligneous vapour and burned in the furnace. Since the "3R Clean Coal Carbonisation Plant" is equipped with a flue gases cleaning system, the SO2 emission level will not exceed 5 mg/m3. The charcoal of the sapwood portion of sleepers and that of the average sleeper wood will contain 0.22% and 0.035% of sulphur, respectively. The increase of the carbonisation temperature does not substantially decrease the sulphur content in charcoal, although it is sufficiently low, and the charcoal can be co-fired with clean coal. The considered process is suitable for small power plants, if the biomass input in the common energy balance is 5 to 10%. If the mean distance of sleepers transportation for Central and Eastern Europe is estimated not to exceed 200 km, the co-combustion of clean coal and carbonized sleepers would be an acceptable option from the environmental and economic points of view.

Occupational Exposures During Routine Activities in Coal-Fueled Power Plants

Limited information is available on occupational exposures during routine, nonoutage work activities in coal-fueled power plants. This study evaluated occupational exposures to the principal contaminants in the facilities, including respirable dust (coal dust), arsenic, noise, asbestos, and heat stress. The data were collected over a 3-month period, during the summer of 2001, in 5 facilities that were chosen to be representative of the coal-fueled power plants of a large southeastern power-generating company. Each of the facilities was divided into 5 similar exposure groups based on previous exposure assessments and job tasks performed. From 4 of the 5 facilities, 392 air samples and 302 noise samples were collected with approximately 50 respirable coal dust, 32 arsenic, 15 asbestos, and 70 noise samples from each of the 4 plants. One of the previously surveyed facilities was also evaluated for heat stress, and 1 additional coal-fueled power plant was surveyed for a total of 20 personal heat stress samples. Personal monitors and area WBGT monitors were used. Of the nearly 400 air samples collected, only 1 exceeded the allowable occupational exposure value. For the noise samples, 55 (∼ 18%) were equal to or greater than the Occupational Safety and Health Administration (OSHA) 8-hour hearing conservation program level of 85 dBA, and 12 (∼ 4%) were equal to or greater than the OSHA 8-hour permissible exposure level of 90 dBA. Heat stress monitoring at the facilities indicates that 26% of the 1-hour TWAs were exceeded for one or all of the recommended heat stress limits. The data also concluded that some work sites were above the heat stress ceiling values recommended by the National Institute for Occupational Safety and Health (NIOSH). Four of the 20 employees personally monitored exceeded the recommended limits for heart rate or body core temperature. This suggests there is a potential for heat strain if signs and symptoms are ignored. Recommendations are made to better control the heat stress exposure.

USA plans pollution-free power plant of the future

Development of the FutureGen geologic storage site in Morgan County Illinois is part of a larger project to design, build, and operate a commercial-scale carbon capture and storage (CCS) system capable of capturing, treating, and storing the CO2 off-gas from an oxy-combustion coal-fueled power plant located in Meredosia, Illinois. The geological storage site is designed to capture approximately 1.1 million metric tons (Mt) of CO2 each year. To support the selection and design of the site, a comprehensive characterization effort was conducted in order to acquire fundamental subsurface site specific information. These characterization activities included seismic surveys coring, geophysical wireline logging, hydrologic testing and geomechanical testing. The characterization results combined with pertinent research literature were used to build a conceptual model of the site, which in turn informed the development of computer models. Collectively this work supported both the design work and the permitting under the U.S. Environmental Protection Agency's class VI Underground Injection Control (UIC) permit process which was developed specifically for CO2 injection. The detailed design of the injection wells and associated monitoring network were completed in early 2014 and in August 2014 the site received the first issued set of class VI UIC permits in the Unites States for the planned injection wells.

High efficiency coal-fired power plant of the future

In this work a novel coal fueled power plant, which combines coal gasification and solid oxide fuel cell technology, is presented. The cycle is a modification of an earlier one proposed by the same authors [Lobachyov and Richter, Journal of Energy Resources Technology, 1996, 188]. It retains most of the elements of the previous plant: Conoco CO 2 acceptor gasification process, solid oxide fuel cell and state-of-the-art gas turbines. A key difference between the previous and the new cycle is a different heat recovery concept. Instead of using the sensible heat of the cathode exhaust for the coal gasification process, the fuel not oxidized in the fuel cell is burnt to provide this heat. This new concept allows us to simplify the cycle and makes its performance less dependent on the pressure drop in different components of the cycle. Further, it considerably reduces the exergy loss in the gas turbine by eliminating exergetically inefficient turbine blade cooling. The new cycle achieves a gain in the overall efficiency of more than two percentage points under the same operating parameters. At a maximum system pressure of 10 bar and an anticipated solid oxide fuel cell voltage of 0.7 V the overall thermal efficiency is approximately 63%.

Emission factors and annual emissions of bulk and trace elements from oil shale fueled power plants

Measurements were carried out to investigate the emission factors and annual emissions of bulk and trace elements from two large oil shale fueled power plants in northeastern Estonia. The samples from fuel and different ash fractions were collected at the same time as the SO 2, NO x and fly ash concentrations in the stack gases were measured at the power plants. The elemental concentrations of 30 elements in the fuel, bottom ash, ash from super heater and economizer, cyclone and electrostatic precipitator ash, and fly ash were analysed by ICP-AES, ICP-MS or INAA. According to the balance studies, based on analyses of the fuel and different ash fractions, 40–50% of sulphur and selenium, and 25–35% of arsenic, cadmium and thallium are released in the gas phase. Other elements, except for chlorine, bromine and iodine, are retained in the ash fraction by over 90%. The emission factor for SO 2 in oil shale fueled power plants is on the same level and the emission factor for NO x one third of that in coal fueled power plants. The fly ash emission factor of oil shale fueled power plants, 1100 mg/MJ, is about 20 times higher than in coal fueled power plants. Due to the large size of these oil shale fueled power plants (electricity output 1390 and 1610 MW) and high fly ash emission factors, the total annual emissions of many elements, both toxic and non-toxic, are very high. For example, the arsenic and lead emissions are 12 and 36 tons per year, respectively, and calcium emissions 36 000 tons/year.

Integration of coal utilization and environmental control in integrated gasification combined cycle systems

Integrated gasification combined cycle (IGCC) systems are a new generation of coal-fueled power generation technologies which embody the concept of integrated environmental control. IGCC systems are capable of significantly lower discharge rates of gaseous, liquid, and solid wastes relative to conventional coal-based systems. However, because few IGCC concepts have been demonstrated at a commercial scale, there is significant uncertainty regarding the technical and environmental performance of many of these systems in full-scale applications. Examples of IGCC system concepts involving both cold and hot gas cleanup are evaluated probabilistically to provide insights into the resulting differences in plant performance, emissions, and cost. For the specific technologies evaluated here, hot gas cleanup offers the potential for higher efficiency and lower cost than cold gas cleanup, but additional considerations may be required to reduce NO, emissions.

High efficiency coal fueled power generation

Coal will remain the primary fuel for power generation in the United States because of the large capacity of existing power plants, the low cost and widespread availability. It is anticipated that higher efficiency power generation cycles which are based upon coal gasification will become the optimum choice for new coal-based power plants, beginning in the mid-1990s. This assmes that currently planned demonstration projects are successful and that advancedpower generation equipment, including gas turbines firing at temperatures of 2,300F and above and molten carbonate fuel cells become comercially available. These cycles, including Integrated Gasification Molten Carbonate Fuel Cells, Integrated Gasification Combined Cycles, and Advanced Pressurized Fluidized Bed Combustion can produce electricity with fuel requirements in the range of 6,000 – 8,000 Btu (HHV)/kWh.

Photosynthetic efficiency optimization studies with the macroalga Gracilaria tikvihae: Implications for CO 2 emission control from power plants

The photosynthetic efficiency (PE) with which the macroalga Gracilaria tikvihae converts visible light energy into chemical energy was studied as a function of irradiance, temperature, and salinity in tumble culture systems at the Natural Energy Laboratory of Hawaii. The photosynthesis/irradiance curve exhibited a typical hyperbolic shape, the associated PEs being a maximum at a visible irradiance of about 500 kcal m −2 day −1. The highest PEs were obtained in seawater diluted by 10% with freshwater; the maximum PEs under these conditions exceeded 7% in full sunlight and 12% in the region of optimal irradiance. PEs were almost identical at 21°C and 25°C, but declined sharply as the temperature was reduced below 21°C. Conversion of the algal biomass to methane by anaerobic fermentation resulted in conversion efficiencies as high as 22% at a detention time of 15 days. This efficiency is substantially higher than results reported in an earlier study, the difference apparently reflecting the use of freshwater rather than seawater as the fermentation medium. To the extent that CO 2 emissions from eletric power plants are reduced by scrubbing the stack gases, growth of algae such as G. tikvihae may be the most logical way to utilize the CO 2. If 20% of the CO 2 presently emitted by coal-fueled power plants in the US were used to grow algae, an area of land equal to roughly 1% of the area of the United States would be required for the growth of the algae.

Cooper-Bessemer Coal-Fueled Engine System—Progress Report

Single-cylinder engine tests were conducted as part of a long-range effort to develop a technology base for coal-fueled stationary modular power plants based on the Cooper-Bessemer LS Series four-stroke diesel engine. These engine test results established the new state of development for this technology as well as setting priorities for the remaining R&D effort on specific components. The current outlook on the overall economics of coal diesel power is presented, indicating that CWS processing cost dominates the question of economic feasibility. A description of the coal-tolerant fuel injection system development is also given. Wear results indicate that nozzle erosion is the critical element in extending the duration of continuous engine operation. Substantial nozzle wear was observed in just two hours of CWS operation. The ash content of the coal was found to affect the wear rate of the ring set as well as the nozzle tip. Combustion results indicate that the natural gas jet cell is a viable ignition aid and that the variable area poppet nozzle, which lends itself to the use of durable coatings, provides satisfactory engine performance.

Environmental Aspects of Coal-Fueled Diesel Engines

Conventional diesel engines are considered by some to be contributors to environmental problems since they emit NOx, a suspected acid rain precursor. Initial testing has shown that CWS-fueled diesels emit substantially reduced NOx emissions. While emissions of particulates and SOx may be potentially higher with coal fuels, assessment of the control technology indicates excellent potential for meeting existing and future standards for these emissions. As a result of activities managed by the Morgantown Energy Technology Center, the economic and technical feasibility of CWS-fueled diesel engines has been determined. Recently, both General Electric and A. D. Little/Cooper Bessemer were selected for 5-year contracts aimed at developing by 1993 the components and subsystems necessary for subsequent private sector demonstration and commercialization of coal-fueled diesel power systems. The development of these CWS-fueled systems will necessitate the application of hot gas cleanup contaminant control technology to ensure that the systems burn coal in an environmentally sound manner. The objective of this paper is to discuss the environmental concerns, emission goals, and the control methodologies, devices, and strategies that will be used to ensure CWS-fueled diesel engines will meet current and potential environmental standards.

Emission Characteristics and Control Technology for Stationary Coal-Fueled Diesel Engines

Emissions of primary concern for coal-fueled diesel cogeneration and electric power plants are nitrogen oxides, sulfur dioxide, particulate matter, and aromatic hydrocarbons. In addition, the exhaust particulate size distribution and ash content are relevant to durability of the exhaust valves, turbocharger, and other engine components. This paper summarizes preliminary measurements of “uncontrolled” emissions in the exhaust of a Cooper-Bessemer 33-cm (13-in.) bore, 400 rpm, single-cylinder research engine, operated on “engine-grade” coal-water fuel (0.5 percent ash, 1 percent sulfur, 8 μm mean size coal). Based on these results, we present a preliminary evaluation of emission control options for satisfying hypothetical future emission standards for 2–50 MW power plants. The paper describes coal-diesel component subsystems such as (a) “reburning” for reducing NOx and hydrocarbon emissions, (b) high- and low-temperature injection of calcium sorbents for SO2 capture, and (c) high-temperature bag filters for control of fine particles. The expected performance of a conceptual, integrated control system is presented.

Respiratory symptoms and air pollution changes in children: the Gardanne Coal-Basin Study.

The influence of daily changes in sulfur dioxide (SO2) levels on the induction of respiratory symptoms was studied during the 1983-1984 winter in 450 children, aged 9 to 11 yr, living in the Gardanne coal-basin, France. In this area, SO2 originates mainly from a coal-fueled power plant. The mean SO2 level during the winter was 22 micrograms/m3 in low-pollution areas and 93 micrograms/m3 in polluted areas, with daily SO2 levels up to 356 micrograms/m3. Children completed a daily diary about respiratory symptoms. In the polluted communities only we demonstrated a significant association between daily SO2 levels (after controlling for temperature and respirable particle variations) and prevalence of upper and lower respiratory symptoms. However, in each polluted town, and for each respiratory symptom, there was no evidence for either a latency period or a delay in the effects of pollutants. Mean daily temperature was also closely correlated with upper and lower respiratory symptoms in most of the polluted and some low-pollution communities. In a second step, the prevalence of respiratory symptoms in each town was compared, during two 2-wk periods, with air pollution levels; higher prevalences were found during the pollution period. In conclusion, moderate daily changes in SO2 levels induce a significant but transient increase in the prevalence of respiratory symptoms in children.