Coal beneficiation by gas agglomeration

Science.gov (United States)

Wheelock, Thomas D.; Meiyu, Shen

2003-10-14

Coal beneficiation is achieved by suspending coal fines in a colloidal suspension of microscopic gas bubbles in water under atmospheric conditions to form small agglomerates of the fines adhered by the gas bubbles. The agglomerates are separated, recovered and resuspended in water. Thereafter, the pressure on the suspension is increased above atmospheric to deagglomerate, since the gas bubbles are then re-dissolved in the water. During the deagglomeration step, the mineral matter is dispersed, and when the pressure is released, the coal portion of the deagglomerated gas-saturated water mixture reagglomerates, with the small bubbles now coming out of the solution. The reagglomerate can then be separated to provide purified coal fines without the mineral matter.

Geological evaluation on productibility of coal seam gas; Coal seam gas no chishitsugakuteki shigen hyoka ni tsuite

Energy Technology Data Exchange (ETDEWEB)

Fujii, K [University of Shizuoka, Shizuoka (Japan). Faculty of Education

1996-09-01

Coal seam gas is also called coal bed methane gas, indicating the gas existing in coal beds. The gas is distinguished from the oil field based gas, and also called non-conventional type gas. Its confirmed reserve is estimated to be 24 trillion m {sup 3}, with the trend of its development seen worldwide as utilization of unused resource. For the necessity of cultivating relevant technologies in Japan, this paper considers processes of production, movement, stockpiling, and accumulation of the gas. Its productibility is controlled by thickness of a coal bed, degree of coalification, gas content, permeability, groundwater flow, and deposition structure. Gas generation potential is evaluated by existing conditions of coal and degree of coalification, and methane production by biological origin and thermal origin. Economically viable methane gas is mainly of the latter origin. Evaluating gas reserve potential requires identification of the whole mechanism of adsorption, accumulation and movement of methane gas. The gas is expected of effect on environmental aspects in addition to availability as utilization of unused energy. 5 figs.

Biological conversion of coal synthesis gas to methane

Energy Technology Data Exchange (ETDEWEB)

Barik, S; Corder, R E; Clausen, E C; Gaddy, J L

1987-09-01

High temperatures and pressures are required, and therefore, high costs incurred during catalytic upgrading of coal synthesis gas to methane. Thus, the feasibility of biological reactions in converting synthesis gas to methane has been demonstrated in mixed and pure cultures. Complete conversion has been achieved in 2 hours with a mixed culture, and 45 minutes to 1.5 hours in pure cultures of P. productus and Methanothrix sp.. Typical sulfur levels involved during the process are found not to inhibit the bacteria and so sulfur does not have to be removed prior to biomethanation. Preliminary economic analyses indicate that coal gas may be biologically methanated for 50-60 cents/million Btu. Further studies with pure culture bacteria and increased pressure are expected to enhance biomethanation economics.

Quantifying the costs of electricity generation in Alberta - modelling Alberta with nuclear power generation in place of coal and natural gas

Energy Technology Data Exchange (ETDEWEB)

Toor, J.; Donev, J.M.K.C., E-mail: jstoor@ucalgary.ca, E-mail: jmdonev@ucalgary.ca [Univ. of Calgary, Calgary, AB (Canada)

2014-07-01

The study determines the externality impacts on Alberta assuming the use nuclear power instead of coal and natural gas. For historical time (1976-2006) it was found that replacing coal generation with nuclear power could have displaced over a million kilotons (kt) of Carbon dioxide (CO{sub 2}) release to the atmosphere, prevented at least 7000 premature deaths and saved a mean value of over $33.1 Billion dollars (2007 USD) at the cost of storing 20.7 kt of spent nuclear fuel ($11.5 Billion). The same calculations were also made for a projection period (2006-2101) and also for the replacement of natural gas with nuclear power. (author)

Quantifying the costs of electricity generation in Alberta - modelling Alberta with nuclear power generation in place of coal and natural gas

International Nuclear Information System (INIS)

Toor, J.; Donev, J.M.K.C.

2014-01-01

The study determines the externality impacts on Alberta assuming the use nuclear power instead of coal and natural gas. For historical time (1976-2006) it was found that replacing coal generation with nuclear power could have displaced over a million kilotons (kt) of Carbon dioxide (CO 2 ) release to the atmosphere, prevented at least 7000 premature deaths and saved a mean value of over $33.1 Billion dollars (2007 USD) at the cost of storing 20.7 kt of spent nuclear fuel ($11.5 Billion). The same calculations were also made for a projection period (2006-2101) and also for the replacement of natural gas with nuclear power. (author)

Economic aspects of advanced coal-fired gas turbine locomotives

Science.gov (United States)

Liddle, S. G.; Bonzo, B. B.; Houser, B. C.

1983-01-01

Increases in the price of such conventional fuels as Diesel No. 2, as well as advancements in turbine technology, have prompted the present economic assessment of coal-fired gas turbine locomotive engines. A regenerative open cycle internal combustion gas turbine engine may be used, given the development of ceramic hot section components. Otherwise, an external combustion gas turbine engine appears attractive, since although its thermal efficiency is lower than that of a Diesel engine, its fuel is far less expensive. Attention is given to such a powerplant which will use a fluidized bed coal combustor. A life cycle cost analysis yields figures that are approximately half those typical of present locomotive engines.

Non-mine technology of hydrocarbon resources production at complex development of gas and coal deposits

International Nuclear Information System (INIS)

Saginov, A.S.; Adilov, K.N.; Akhmetbekov, Sh.U.

1997-01-01

Non-mine technology of coal gas seams exploitation is new geological technological method of complex exploitation of coal gas deposits. The method allows sequentially to extract hydrocarbon resources in technological aggregative-mobile condensed states. According to natural methane content in seams the technology includes: methane extraction from sorption volume where it is bounded up with coal; gas output intensification of coal is due to structural changes of substance at the cost of physico-chemical treatment of seam; increase of seam permeability by the methods of active physical and physico-chemical actions on coal seam (hydro-uncovering, pneumatic hydro action etc.). Pilot testing shows efficiency of well mastering with help of depth pumps. In this case works of action of pumping out of operating liquid and gas extraction from coal seam are integrated

Life-cycle comparison of greenhouse gas emissions and water consumption for coal and shale gas fired power generation in China

International Nuclear Information System (INIS)

Chang, Yuan; Huang, Runze; Ries, Robert J.; Masanet, Eric

2015-01-01

China has the world's largest shale gas reserves, which might enable it to pursue a new pathway for electricity generation. This study employed hybrid LCI (life cycle inventory) models to quantify the ETW (extraction-to-wire) GHG (greenhouse gas) emissions and water consumption per kWh of coal- and shale gas-fired electricity in China. Results suggest that a coal-to-shale gas shift and upgrading coal-fired power generation technologies could provide pathways to less GHG and water intensive power in China. Compared to different coal-fired generation technologies, the ETW GHG emissions intensity of gas-fired CC (combined cycle) technology is 530 g CO 2 e/kWh, which is 38–45% less than China's present coal-fired electricity. Gas-fired CT (combustion turbine) technology has the lowest ETW water consumption intensity at 960 g/kWh, which is 34–60% lower than China's present coal-fired electricity. The GHG-water tradeoff of the two gas-fired power generation technologies suggests that gas-fired power generation technologies should be selected based on regional-specific water resource availabilities and electricity demand fluctuations in China. However, the low price of coal-fired electricity, high cost of shale gas production, insufficient pipeline infrastructures, and multiple consumers of shale gas resources may serve as barriers to a coal-to-shale gas shift in China's power sector in the near term. - Highlights: • The GHG and water footprints of coal- and shale gas-fired electricity are estimated. • A coal-to-shale gas shift can enable less GHG and water intensive power in China. • The GHG emissions of shale gas-fired combined cycle technology is 530 g CO 2 e/kWh. • The water consumption of shale gas-fired combustion turbine technology is 960 g/kWh. • Shale gas-fired power generation technologies selection should be regional-specific

Fast and safe gas detection from underground coal fire by drone fly over

International Nuclear Information System (INIS)

Dunnington, Lucila; Nakagawa, Masami

2017-01-01

Underground coal fires start naturally or as a result of human activities. Besides burning away the important non-renewable energy resource and causing financial losses, burning coal seams emit carbon dioxide, carbon monoxide, sulfur oxide and methane, and is a leading cause of smog, acid rain, global warming, and air toxins. In the U.S. alone, the combined cost of coal-fire remediation projects that have been completed, budgeted, or projected by the U.S. Department of the Interior's Office of Surface Mining Remediation and Enforcement (OSM), exceeds $1 billion. It is estimated that these fires generate as much as 3% of the world's annual carbon dioxide emissions and consume as much as 5% of its minable coal. Considering the magnitude of environmental impact and economic loss caused by burning underground coal seams, we have developed a new, safe, reliable surface measurement of coal fire gases to assess the nature of underground coal fires. We use a drone mounted with gas sensors. Drone collected gas concentration data provides a safe alternative for evaluating the rank of a burning coal seam. In this study, a new method of determining coal rank by gas ratios is developed. Coal rank is valuable for defining parameters of a coal seam such as burn temperature, burn rate, and volume of burning seam. - Graphical abstract: Concluding Figure for Gas Ratios: Plotted points and ranges of adjusted literature data. Stars represent bituminous and subbituminous coal types; Ovals represent lignite. - Highlights: • Recognize underground coal fire as a potential source of energy. • Developed a creative, safe, reliable and fast gas detection method. • Developed a concept of gas ratio measurement method that can provide more accurate description of underground burning coal resource.

Coal contract cost reduction through resale of coal

International Nuclear Information System (INIS)

Simon, R.

1990-01-01

The weak coal market of the 1980's has enabled utilities and other users of coal to enjoy stable or falling prices for coal supplies. Falling prices for coal stimulated the renegotiation of numerous coal contracts in recent years, as buyers look to take advantage of lower fuel prices available in the marketplace. This paper examines the use of coal resale transactions as a means of reducing fuel costs, and analyzes the benefits and risks associated with such transactions

Use of a Nuclear High Temperature Gas Reactor in a Coal-To-Liquids Process

International Nuclear Information System (INIS)

Robert S. Cherry; Richard A. Wood

2006-01-01

AREVA's High Temperature Gas Reactor (HTGR) can potentially provide nuclear-generated, high-level heat to chemical process applications. The use of nuclear heat to help convert coal to liquid fuels is particularly attractive because of concerns about the future availability of petroleum for vehicle fuels. This report was commissioned to review the technical and economic aspects of how well this integration might actually work. The objective was to review coal liquefaction processes and propose one or more ways that nuclear process heat could be used to improve the overall process economics and performance. Shell's SCGP process was selected as the gasifier for the base case system. It operates in the range of 1250 to 1600 C to minimize the formation of tars, oil, and methane, while also maximizing the conversion of the coal's carbon to gas. Synthesis gas from this system is cooled, cleaned, reacted to produce the proper ratio of hydrogen to carbon monoxide and fed to a Fischer-Tropsch (FT) reaction and product upgrading system. The design coal-feed rate of 18,800 ton/day produces 26.000 barrels/day of FT products. Thermal energy at approximately 850 C from a HTGR does not directly integrate into this gasification process efficiently. However, it can be used to electrolyze water to make hydrogen and oxygen, both of which can be beneficially used in the gasification/FT process. These additions then allow carbon-containing streams of carbon dioxide and FT tail-gas to be recycled in the gasifier, greatly improving the overall carbon recovery and thereby producing more FT fuel for the same coal input. The final process configuration, scaled to make the same amount of product as the base case, requires only 5,800 ton/day of coal feed. Because it has a carbon utilization of 96.9%, the process produces almost no carbon dioxide byproduct Because the nuclear-assisted process requires six AREVA reactors to supply the heat, the capital cost is high. The conventional plant is

Economic comparison of clean coal generating technologies with natural gas-combined cycle systems

International Nuclear Information System (INIS)

Sebesta, J.J.; Hoskins, W.W.

1990-01-01

This paper reports that there are four combustion technologies upon which U.S. electric utilities are expected to rely for the majority of their future power generating needs. These technologies are pulverized coal- fired combustion (PC); coal-fired fluidized bed combustion (AFBC); coal gasification, combined cycle systems (CGCC); and natural gas-fired combined cycle systems (NGCC). The engineering and economic parameters which affect the choice of a technology include capital costs, operating and maintenance costs, fuel costs, construction schedule, process risk, environmental and site impacts, fuel efficiency and flexibility, plant availability, capacity factors, timing of startup, and the importance of utility economic and financial factors

Impacts of carbon pricing, brown coal availability and gas cost on Czech energy system up to 2050

International Nuclear Information System (INIS)

Rečka, L.; Ščasný, M.

2016-01-01

A dynamic partial equilibrium model, TIMES (​The Integrated MARKAL-EFOM System), is built to optimize the energy system in a post-transition European country, the Czech Republic. The impacts of overall nine scenarios on installed capacity, capital and fuel costs, air quality pollutant emission, emission of CO_2 and environmental and health damage are quantified for a period up to 2050. These scenarios are built around three different price sets of the EUA (EU allowance) to emit greenhouse gasses alongside a policy that retains the ban on brown coal mining in two Czech mines, a policy that will allow the re-opening of mining areas under this ban (i.e. within the territorial ecological limits), and a low natural gas price assumption. We found that the use of up until now dominant brown coal will be significantly reduced in each scenario, although reopening the coal mines will result in its smaller decline. With low EUA price, hard coal will become the dominant fuel in electricity generation, while nuclear will overtake this position with a 51% or even 65% share assuming the central price of EUA, or high EUA price, respectively. The low price of natural gas will result in an increasing gas share from an almost zero share recently up to about 42%. This stimulus does not however appear at all with low EUA price. Neither of these scenarios will achieve the renewable energy sources 2030 targets and only a high EUA price will lead to almost full de-carbonization of the Czech power system, with fossil fuels representing only 16% of the energy mix. The low EUA price will result in an increase in CO_2 emissions, whereas the high EUA price will reduce CO_2 emission by at least 81% compared to the 2015 reference level. Those scenarios that will result in CO_2 emission reduction will also generate ancillary benefits due to reduction in air quality emissions, on average over the entire period, at least at 38€ per t of avoided CO_2, whereas scenarios that will lead to CO_2

Study of China's coal supply cost

International Nuclear Information System (INIS)

Schneider, K.

1998-01-01

The Department of Primary Industries and Energy is funding a joint research project between ABARE and the Energy Research Institute of China's State Planning Commission, China's leading organisation undertaking policy-related energy sector research. Together, the two organisations will analyse the economic costs and impacts of moving large quantities of coal from China's northern coal fields to, power stations in the rapidly growing south-eastern coastal provinces. The study will also compare the true economic costs of using domestic coal - including the costs of subsidies on coal production and transport - with the costs of using imported coal. ABARE will use its dynamic model, MEGABARE, to undertake ky parts of the study, taking into account the complex linkages between sectors in an economy and between different economies

Gas associated to coal in Colombia. An energetic alternative of non-conventional gas fields

International Nuclear Information System (INIS)

Garcia Gonzalez, Mario

2005-01-01

Colombia possesses the biggest coal reserves of Latin America, in such a way that the potential reserves of Gas Associated to the Coal (GAC) they are of great magnitude; the paper includes topics like the generation of the gas associated to the coal, geologic factors that control the gas occurrence, development of the gas associated to the coal in the world, and potential reserves of gas associated to the coal in Colombia

Effects of Loading Rate on Gas Seepage and Temperature in Coal and Its Potential for Coal-Gas Disaster Early-Warning

Directory of Open Access Journals (Sweden)

Chong Zhang

2017-08-01

Full Text Available The seepage velocity and temperature externally manifest the changing structure, gas desorption and energy release that occurs in coal containing gas failure under loading. By using the system of coal containing gas failure under loading, this paper studies the law of seepage velocity and temperature under different loading rates and at 1.0 MPa confining pressure and 0.5 MPa gas pressure, and combined the on-site results of gas pressure and temperature. The results show that the stress directly affects the seepage velocity and temperature of coal containing gas, and the pressure and content of gas have the most sensitivity to mining stress. Although the temperature is not sensitive to mining stress, it has great correlation with mining stress. Seepage velocity has the characteristic of critically slowing down under loading. This is demonstrated by the variance increasing before the main failure of the samples. Therefore, the variance of seepage velocity with time and temperature can provide an early warning for coal containing gas failing and gas disasters in a coal mine.

Fast and safe gas detection from underground coal fire by drone fly over.

Science.gov (United States)

Dunnington, Lucila; Nakagawa, Masami

2017-10-01

Underground coal fires start naturally or as a result of human activities. Besides burning away the important non-renewable energy resource and causing financial losses, burning coal seams emit carbon dioxide, carbon monoxide, sulfur oxide and methane, and is a leading cause of smog, acid rain, global warming, and air toxins. In the U.S. alone, the combined cost of coal-fire remediation projects that have been completed, budgeted, or projected by the U.S. Department of the Interior's Office of Surface Mining Remediation and Enforcement (OSM), exceeds $1 billion. It is estimated that these fires generate as much as 3% of the world's annual carbon dioxide emissions and consume as much as 5% of its minable coal. Considering the magnitude of environmental impact and economic loss caused by burning underground coal seams, we have developed a new, safe, reliable surface measurement of coal fire gases to assess the nature of underground coal fires. We use a drone mounted with gas sensors. Drone collected gas concentration data provides a safe alternative for evaluating the rank of a burning coal seam. In this study, a new method of determining coal rank by gas ratios is developed. Coal rank is valuable for defining parameters of a coal seam such as burn temperature, burn rate, and volume of burning seam. Copyright © 2017 Elsevier Ltd. All rights reserved.

Evaluation of dense-phase ultrafine coal (DUC) as a fuel alternative for oil- and gas-designed boilers and heaters. Final report

Energy Technology Data Exchange (ETDEWEB)

1986-12-01

Utility and industrial firms currently using oil- and gas-fired boilers have an interest in substitution of coal for oil and gas as the primary boiler fuel. This interest stems from coal`s two main advantages over oil and gas-lower cost and security of supply. Recent efforts in the area of coal conversion have been directed to converting oil- and gas- fired boilers which were originally designed for coal-firing or were designed with some coal-firing capability. Boilers designed exclusively for oil- or gas-firing have not been considered viable candidates for coal conversion because they generally require a significant capacity derating and extensive and costly modifications. As a result, conversion of boilers in this class to coal-firing has generally been considered unattractive. Renewed interest in the prospects for converting boilers designed exclusively for oil- and gas-firing to coal firing has centered around the concept of using ``ultra fine`` coal as opposed to ``conventional grind`` pulverized coal. The main distinction being the finer particle size to which the former is ground. This fuel type may have characteristics which ameliorate many of the boiler problems normally associated with pulverized coal-firing. The overall concept for ultrafine coal utilization is based on a regional large preparation plant with distribution of a ready to fire fuel directly to many small users. This differs from normal practice in which final coal sizing is performed in pulverizers at the user`s site.

Integrated process for synthetic natural gas production from coal and coke-oven gas with high energy efficiency and low emission

International Nuclear Information System (INIS)

Man, Yi; Yang, Siyu; Qian, Yu

2016-01-01

Highlights: • A novel coal and coke-oven gas to SNG (CGtSNG) process is proposed. • Energy efficiency of CGtSNG increases 8% compared to coal-to-SNG process. • CGtSNG reduces 60% CO_2 emission and 72% effluent discharge. • CGtSNG proposes an idea of using redundant coke-oven gas for producing SNG production. - Abstract: There was a rapid development of coal to synthetic natural gas (SNG) projects in the last few years in China. The research from our previous work and some other researchers have found coal based SNG production process has the problems of environmental pollution and emission transfer, including CO_2 emission, effluent discharge, and high energy consumption. This paper proposes a novel co-feed process of coal and coke-oven gas to SNG process by using a dry methane reforming unit to reduce CO_2 emissions, more hydrogen elements are introduced to improve resource efficiency. It is shown that the energy efficiency of the co-feed process increases by 4%, CO_2 emission and effluent discharge is reduced by 60% and 72%, whereas the production cost decreases by 16.7%, in comparison to the conventional coal to SNG process. As coke-oven gas is a waste gas in most of the coking plant, this process also allows to optimize the allocation of resources.

Production of synthesis gas and methane via coal gasification utilizing nuclear heat

International Nuclear Information System (INIS)

van Heek, K.H.; Juentgen, H.

1982-01-01

The steam gasificaton of coal requires a large amount of energy for endothermic gasification, as well as for production and heating of the steam and for electricity generation. In hydrogasification processes, heat is required primarily for the production of hydrogen and for preheating the reactants. Current developments in nuclear energy enable a gas cooled high temperature nuclear reactor (HTR) to be the energy source, the heat produced being withdrawn from the system by means of a helium loop. There is a prospect of converting coal, in optimal yield, into a commercial gas by employing the process heat from a gas-cooled HTR. The advantages of this process are: (1) conservation of coal reserves via more efficient gas production; (2) because of this coal conservation, there are lower emissions, especially of CO 2 , but also of dust, SO 2 , NO/sub x/, and other harmful substances; (3) process engineering advantages, such as omission of an oxygen plant and reduction in the number of gas scrubbers; (4) lower gas manufacturing costs compared to conventional processes. The main problems involved in using nuclear energy for the industrial gasification of coal are: (1) development of HTRs with helium outlet temperatures of at least 950 0 C; (2) heat transfer from the core of the reactor to the gas generator, methane reforming oven, or heater for the hydrogenation gas; (3) development of a suitable allothermal gas generator for the steam gasification; and (4) development of a helium-heated methane reforming oven and adaption of the hydrogasification process for operation in combination with the reactor. In summary, processes for gasifying coal that employ heat from an HTR have good economic and technical prospects of being realized in the future. However, time will be required for research and development before industrial application can take place. 23 figures, 4 tables. (DP)

Determination of leveled costs of electric generation for gas plants, coal and nuclear; Determinacion de costos nivelados de generacion electrica para plantas de gas, carbon y nucleares

Energy Technology Data Exchange (ETDEWEB)

Alonso V, G.; Palacios H, J.C.; Ramirez S, J.R.; Gomez, A. [ININ, 52045 Ocoyoacac, Estado de Mexico (Mexico)]. e-mail: galonso@nuclear.inin.mx

2005-07-01

The present work analyzes the leveled costs of electric generation for different types of nuclear reactors known as Generation III, these costs are compared with the leveled costs of electric generation of plants with the help of natural gas and coal. In the study several discount rates were used to determine their impact in the initial investment. The obtained results are comparable with similar studies and they show that it has more than enough the base of the leveled cost the nuclear option it is quite competitive in Mexico. Also in this study it is also thinks about the economic viability of a new nuclear power station in Mexico. (Author)

Gas Permeability Evolution Mechanism and Comprehensive Gas Drainage Technology for Thin Coal Seam Mining

Directory of Open Access Journals (Sweden)

Fangtian Wang

2017-09-01

Full Text Available A thin coal seam mined as a protective coal seam above a gas outburst coal seam plays a central role in decreasing the degree of stress placed on a protected seam, thus increasing gas permeability levels and desorption capacities to dramatically eliminate gas outburst risk for the protected seam. However, when multiple layers of coal seams are present, stress-relieved gas from adjacent coal seams can cause a gas explosion. Thus, the post-drainage of gas from fractured and de-stressed strata should be applied. Comprehensive studies of gas permeability evolution mechanisms and gas seepage rules of protected seams close to protective seams that occur during protective seam mining must be carried out. Based on the case of the LongWall (LW 23209 working face in the Hancheng coal mine, Shaanxi Province, this paper presents a seepage model developed through the FLAC3D software program (version 5.0, Itasca Consulting Group, Inc., Minneapolis, MI, USA from which gas flow characteristics can be reflected by changes in rock mass permeability. A method involving theoretical analysis and numerical simulation was used to analyze stress relief and gas permeability evolution mechanisms present during broken rock mass compaction in a goaf. This process occurs over a reasonable amount of extraction time and in appropriate locations for comprehensive gas extraction technologies. In using this comprehensive gas drainage technological tool, the safe and efficient co-extraction of thin coal seams and gas resources can be realized, thus creating a favorable environment for the safe mining of coal and gas outburst seams.

Kyoto, coal and sharing the cost burden

International Nuclear Information System (INIS)

Daley, J.

1998-01-01

Parties to the UN Framework Convention on Climate Change (the Rio Treaty) at their first conference in 1995 agreed that the commitments entered into under the Convention were 'not adequate' to achieve its objective. These nations determined to proceed to strengthen those commitments under a protocol to be prepared for the third conference at Kyoto. Also it was to contain 'quantified emissions limitation objectives' (binding targets) on the industrial countries. For such targets to be consistent with Australia's interests, they would need to recognise Australia's relatively fast population and economic growth (both of which imply relatively faster growth in emissions), the increasing preponderance of energy intensive industries in the Australian economy, and our dependence on the export of energy intensive manufactures (like aluminium and other metals) and direct export of fossil fuels (including coal and natural gas). Major parties to the protocol negotiations - the USA and the EU - were advocates of uniform percentage emissions reductions from 1990 levels. Uniform percentage reductions, however intuitively appealing, impose widely different costs on different parties on account of their different circumstances. Australia would have been penalised by uniform reductions because our projected business-as-usual emissions trajectory is relatively steep, and measures adopted internationally to mitigate greenhouse gas emissions impact disproportionately on this economy (notably on account of reduced demand for Australian coal). The accompanying charts depict ABAREs 'less stringent' emissions scenario - addressing a goal of stabilising industrial countries' emissions of C0 2 rather than reducing them. ABARE's simulation for Australia by sector shows big negative impacts on output of non-ferrous metals, iron and steel, and coal. The metals industries, directly or indirectly are the coal industry's most important domestic customers. It is argued that because of the impact

Cost of mining Eastern coal

International Nuclear Information System (INIS)

Anon.

1990-01-01

This paper, Chapter 7.2.3 of the 'surface mining' reference book, gives an example of how the cost of mining a ton of coal is calculated. Conditions set down are for a coal tract of 50.6 ha in West Virginia, USA to be mined by the contour surface method, the seam being 101.6cm thick. Elements of the costing are: permitting and bonding costs, engineering and construction costs, equipment and other operating expenses (such as hauling and wheeling), royalties, direct taxes and fees, costs of revegetation, and employment costs (payroll and medical expenses). 5 tabs

Conversion of Coal Mine Gas to LNG

Energy Technology Data Exchange (ETDEWEB)

None, None

2016-02-05

This project evolved from a 1995, DOE-NETL competitive solicitation for practical CMM capture and utilization concepts. Appalachian Pacific was one of three companies selected to proceed with the construction and operation of a cost-shared demonstration plant. In the course of trying to proceed with this demonstration plant, AP examined several liquefaction technologies, discussed obtaining rights to coal mine methane with a number of coal companies, explored marketing potential with a wide variety of customers in many sections of the United States, studied in great detail the impact of a carbon credit exchange, and developed a suite of analytical tools with which to evaluate possible project options. In the end, the newness of the product, reluctance on the part of the coal companies to venture away from time tested practices, difficulty with obtaining financing, the failure of a carbon credit market to develop and the emergence of shale derived gas production prevented a demonstration plant from being built.

Analysis of rationality of coal-based synthetic natural gas (SNG) production in China

International Nuclear Information System (INIS)

Li, Hengchong; Yang, Siyu; Zhang, Jun; Kraslawski, Andrzej; Qian, Yu

2014-01-01

To alleviate the problem of the insufficient reserves of natural gas in China, coal-based synthetic natural gas (SNG) is considered to be a promising option as a source of clean energy, especially for urban use. However, recent study showed that SNG will not accomplish the task of simultaneous energy conservation and CO 2 reduction. In this paper, life cycle costing is made for SNG use in three main applications in residential sector: heating, household use, and public transport. Comparisons are conducted between SNG and coal, natural gas, liquefied petroleum gas (LPG), diesel, and methanol. The results show that SNG is a competitive option only for household use. The use of SNG for heating boilers or city buses is not as cost-effective as expected. The biggest shortcoming of SNG is the large amount of pollutants generated in the production stage. At the moment, the use of SNG is promoted by the government. However, as shown in this paper, one can expect a transfer of pollution from the urban areas to the regions where SNG is produced. Therefore, it is suggested that well-balanced set of environmental damage-compensating policies should be introduced to compensate the environmental losses in the SNG-producing regions. - Highlights: • Life cycle costing was applied on the coal-based SNG. • The SNG was compared with conventional fuels of three residential applications. • The SNG is not so cost-effective except of household use. • Ecological compensation policy is useful to deal with the transfer of pollutions

Small, modular, low-cost coal-fired power plants for the international market

Energy Technology Data Exchange (ETDEWEB)

Zauderer, B.; Frain, B.; Borck, B. [Coal Tech Corp., Merion Station, PA (United States); Baldwin, A.L. [Dept. of Energy, Pittsburgh, PA (United States). Pittsburgh Energy Technology Center

1997-12-31

This paper presents recent operating results of Coal Tech`s second generation, air cooled, slagging coal combustor, and its application to power plants in the 1 to 20 MW range. This 20 MMBtu/hour combustor was installed in a new demonstration plant in Philadelphia, PA in 1995. It contains the combustion components of a 1 MWe coal fired power plant, a 17,500 lb/hour steam boiler, coal storage and feed components, and stack gas cleanup components. The plant`s design incorporates improvements resulting from 2,000 hours of testing between 1987 and 1993 on a first generation, commercial scale, air cooled combustor of equal thermal rating. Since operations began in early 1996, a total of 51 days of testing have been successfully completed. Major results include durability of the combustor`s refractory wall, excellent combustion with high ash concentration in the fuel, removal of 95% to 100% of the slag in the combustor, very little ash deposition in the boiler, major reduction of in-plant parasitic power, and simplified power system control through the use of modular designs of sub-systems and computer control. Rapid fuel switching between oil, gas, and coal and turndown of up to a factor of three was accomplished. All these features have been incorporated in advanced coal fired plant designs in the 1 to 20 MWe range. Incremental capital costs are only $100 to $200/kW higher than comparable rated gas or oil fired steam generating systems. Most of its components and subsystems can be factory assembled for very rapid field installation. The low capital, low operating costs, fuel flexibility, and compatibility with very high ash fuels, make this power system very attractive in regions of the world having domestic supplies of these fuels.

Exploitation and use of coal field gas

Energy Technology Data Exchange (ETDEWEB)

Wang, K; Li, Z; Sun, Q

1982-04-25

There are slightly more than 440 mine shafts in the world from which gas is pumped at the same time coal is being mined, the volume pumped being 3.125 billion cubic meters. All the countries of the world today widely use gas as a fuel and as a raw material for the chemical industry. In China 40 percent of the total number of mine shafts are high gas mine shafts. In China, gas is used largely as fuel by the people, to fire boilers, to make formaldehyde, and to make carbon ink. Prospects are good for the exploitation of mine shaft gas that is produced in association with coal. Mine shaft gas is a top quality energy source with an extraction life that is longer than coals. (DP)

Externality costs of the coal-fuel cycle: The case of Kusile Power Station

Directory of Open Access Journals (Sweden)

Nonophile P. Nkambule

2017-09-01

Full Text Available Coal-based electricity is an integral part of daily life in South Africa and globally. However, the use of coal for electricity generation carries a heavy cost for social and ecological systems that goes far beyond the price we pay for electricity. We developed a model based on a system dynamics approach for understanding the measurable and quantifiable coal-fuel cycle burdens and externality costs, over the lifespan of a supercritical coal-fired power station that is fitted with a flue-gas desulfurisation device (i.e. Kusile Power Station. The total coal-fuel cycle externality cost on both the environment and humans over Kusile's lifespan was estimated at ZAR1 449.9 billion to ZAR3 279 billion or 91c/kWh to 205c/kWh sent out (baseline: ZAR2 172.7 billion or 136c/kWh. Accounting for the life-cycle burdens and damages of coal-derived electricity conservatively, doubles to quadruples the price of electricity, making renewable energy sources such as wind and solar attractive alternatives. Significance: The use of coal for electricity generation carries a heavy cost for social and ecological systems that goes far beyond the price we pay for electricity. The estimation of social costs is particularly important to the electric sector because of non-differentiation of electricity prices produced from a variety of sources with potentially very dissimilar environmental and human health costs. Because all electricity generation technologies are associated with undesirable side effects in their fuelcycle and lifespan, comprehensive comparative analyses of life-cycle costs of all power generation technologies is indispensable to guide the development of future energy policies in South Africa.

Life-cycle greenhouse gas emissions of shale gas, natural gas, coal, and petroleum.

Science.gov (United States)

Burnham, Andrew; Han, Jeongwoo; Clark, Corrie E; Wang, Michael; Dunn, Jennifer B; Palou-Rivera, Ignasi

2012-01-17

The technologies and practices that have enabled the recent boom in shale gas production have also brought attention to the environmental impacts of its use. It has been debated whether the fugitive methane emissions during natural gas production and transmission outweigh the lower carbon dioxide emissions during combustion when compared to coal and petroleum. Using the current state of knowledge of methane emissions from shale gas, conventional natural gas, coal, and petroleum, we estimated up-to-date life-cycle greenhouse gas emissions. In addition, we developed distribution functions for key parameters in each pathway to examine uncertainty and identify data gaps such as methane emissions from shale gas well completions and conventional natural gas liquid unloadings that need to be further addressed. Our base case results show that shale gas life-cycle emissions are 6% lower than conventional natural gas, 23% lower than gasoline, and 33% lower than coal. However, the range in values for shale and conventional gas overlap, so there is a statistical uncertainty whether shale gas emissions are indeed lower than conventional gas. Moreover, this life-cycle analysis, among other work in this area, provides insight on critical stages that the natural gas industry and government agencies can work together on to reduce the greenhouse gas footprint of natural gas.

Study for recovery and utilization of coal mine gas in Russia (Kuznetsk coal basin)

Energy Technology Data Exchange (ETDEWEB)

NONE

2000-03-01

For the purpose of reducing greenhouse effect gas emissions in line with the Joint Implementation, a study was conducted on recovery/utilization of methane gas emitted from the Chertinskaya coal mine in the Kuznetsk coal basin area. According to the survey, the methane gas emitted from the Chertinskaya coal mine into the atmospheric air is 26 million to 36 million tons on the levels of the annual coal production between 0.7 million and 1 million tons. However, the monthly gas recovery amount and concentration largely fluctuate, and therefore, the use method to cope with this was studied. The study was now under way, and the electric power production using gas engine was regarded as the best. In this project, only the Chertinskaya mine can generate power of 34,721 MWh. In the whole Kuznetsk coal basin, approximately 200 million m{sup 3} of gas is needed to be removed for safety of the mine. The use of this will probably bring energy substitution of about 128,000 tons/year and CO2 reduction of 2.8 million tons/year. (NEDO)

Production of activated char from Illinois coal for flue gas cleanup

Science.gov (United States)

Lizzio, A.A.; DeBarr, J.A.; Kruse, C.W.

1997-01-01

Activated chars were produced from Illinois coal and tested in several flue gas cleanup applications. High-activity chars that showed excellent potential for both SO2 and NOx removal were prepared from an Illinois No. 2 bituminous coal. The SO2 (120 ??C) and NOx (25 ??C) removal performance of one char compared favorably with that of a commercial activated carbon (Calgon Centaur). The NOx removal performance of the same char at 120 ??C exceeded that of the Centaur carbon by more than 1 order of magnitude. Novel char preparation methods were developed including oxidation/thermal desorption and hydrogen treatments, which increased and preserved, respectively, the active sites for SO2 and NOx adsorption. The results of combined SO2/NOx removal tests, however, suggest that SO2 and NOx compete for similar adsorption sites and SO2 seems to be more strongly adsorbed than NO. A low-activity, low-cost char was also developed for cleanup of incinerator flue gas. A three-step method involving coal preoxidation, pyrolysis, and CO2 activation was used to produce the char from Illinois coal. Five hundred pounds of the char was tested on a slipstream of flue gas from a commercial incinerator in Germany. The char was effective in removing >97% of the dioxins and furans present in the flue gas; mercury levels were below detectable limits.

Integrated engineering and cost model for management of coal combustion byproducts

Energy Technology Data Exchange (ETDEWEB)

Sevim, H. [Department of Mining Engineering, Southern Illinois University at Carbondale, Carbondale, Illinois (United States); Renninger, S. [US Department of Energy, Morgantown Energy Technology Center, Morgantown, West Virginia (United States)

1998-07-01

An integrated engineering and cost model has been developed as a part of an overall research project for exploring the technical, environmental and economic feasibility of disposing coal combustion byproducts and flue gas desulfurisation products in underground coal mines in Illinois. The features of the model have been keyed in user-friendly software. In this paper, the purpose and the structure of the model are described. The capabilities of the software are illustrated through an example involving transportation of byproducts in containers from a power plant to a mine site, and subsequent placement of the byproducts in a abandoned underground coal mine using a hydraulic injection system. 3 refs.

Impacts of Coal Seam Gas (Coal Bed Methane) Extraction on Water Resources in Australia

Science.gov (United States)

Post, David

2017-04-01

While extraction of methane from shale gas deposits has been the principal source of the recent expansion of the industry in the United States, in Australia extraction of methane from coal bed methane deposits (termed 'coal seam gas' in Australia) has been the focus to date. The two sources of methane share many of the same characteristics including the potential requirement for hydraulic fracturing. However, as coal seam gas deposits generally occur at shallower depths than shale gas, the potential impacts of extraction on surface and groundwater resources may be of even greater concern. In Australia, an Independent Expert Scientific Committee (IESC) has been established to provide scientific advice to federal and state government regulators on the impact that coal seam gas and large coal mining developments may have on water resources. This advice is provided to enable decisions to be informed by the best available science about the potential water-related impacts associated with these developments. To support this advice, the Australian Government Department of the Environment has implemented a programme of research termed 'bioregional assessments' to investigate these potential impacts. A bioregional assessment is defined as a scientific analysis of the ecology, hydrology, geology and hydrogeology of a bioregion with explicit assessment of the potential direct, indirect and cumulative impacts of coal seam gas and large coal mining development on water resources. These bioregional assessments are currently being carried out across large portions of eastern Australia underlain by coal reserves. Further details of the programme and results to date can be found at http://www.bioregionalassessments.gov.au. The bioregional assessment programme has modelled the impacts of coal seam gas development on surface and groundwater resources in three regions of eastern Australia, namely the Clarence-Moreton, Gloucester, and Namoi regions. This presentation will discuss the

Permeability changes in coal resulting from gas desorption

Energy Technology Data Exchange (ETDEWEB)

Levine, J.R.; Johnson, P.W.

1992-11-30

This report documents studies on the effects of gas sorption on coal, with the intent of eventually evaluating how sorption and strain affect permeability. These studies were, carried out at the University of Alabama during the period from 1989 through 1992. Two major experimental methods were developed and used. In the strain experiments, electronic strain gauges were attached to polished blocks of coal in order to measure linear and volumetric swelling due to gas sorption. The effects of bedding plane orientation, of gas type, and of coal type were investigated. In the gravimetric experiment the weight of small samples of coal was measured during exposure to high pressure gases. Sample measurements were corrected for buoyancy effects and for sample swelling, and the results were plotted in the form of Langmuir isotherms. Experiments were conducted to determine the effect of grain size, coal type, moisture, and of sorbant gas. The advantage of this method is that it can be applied to very small samples, and it enabled comparison liptinite versus vitrinite concentrates, and kerogen rich versus kerogen depleted oil shales. Also included is a detailed discussion of the makeup of coal and its effect on gas sorption behavior.

Action of coal gas on plants. II. Action on green plants

Energy Technology Data Exchange (ETDEWEB)

Wehmer, C

1917-01-01

Experiments were performed to determine the effects of coal gas on cress. Although the seeds are not killed by coal gas, they are prevented from germinating. Cress will grow in as much as 30% coal gas, but it will not survive higher concentrations. Coal gas contains both toxic and non-toxic constituents. CO, C/sub 2/H/sub 4/, C/sub 2/H/sub 2/, CS/sub 2/, H/sub 2/S are not toxic at concentrations found in coal gas. The toxic effects of coal gas are not caused by the lack of O/sub 2/, but by minor impurities in the gas.

Boiler briquette coal versus raw coal: Part I--Stack gas emissions.

Science.gov (United States)

Ge, S; Bai, Z; Liu, W; Zhu, T; Wang, T; Qing, S; Zhang, J

2001-04-01

Stack gas emissions were characterized for a steam-generating boiler commonly used in China. The boiler was tested when fired with a newly formulated boiler briquette coal (BB-coal) and when fired with conventional raw coal (R-coal). The stack gas emissions were analyzed to determine emission rates and emission factors and to develop chemical source profiles. A dilution source sampling system was used to collect PM on both Teflon membrane filters and quartz fiber filters. The Teflon filters were analyzed gravimetrically for PM10 and PM2.5 mass concentrations and by X-ray fluorescence (XRF) for trace elements. The quartz fiber filters were analyzed for organic carbon (OC) and elemental carbon (EC) using a thermal/optical reflectance technique. Sulfur dioxide was measured using the standard wet chemistry method. Carbon monoxide was measured using an Orsat combustion analyzer. The emission rates of the R-coal combustion (in kg/hr), determined using the measured stack gas concentrations and the stack gas emission rates, were 0.74 for PM10, 0.38 for PM2.5, 20.7 for SO2, and 6.8 for CO, while those of the BB-coal combustion were 0.95 for PM10, 0.30 for PM2.5, 7.5 for SO2, and 5.3 for CO. The fuel-mass-based emission factors (in g/kg) of the R-coal, determined using the emission rates and the fuel burn rates, were 1.68 for PM10, 0.87 for PM2.5, 46.7 for SO2, and 15 for CO, while those of the BB-coal were 2.51 for PM10, 0.79 for PM2.5, 19.9 for SO2, and 14 for CO. The task-based emission factors (in g/ton steam generated) of the R-coal, determined using the fuel-mass-based emission factors and the coal/steam conversion factors, were 0.23 for PM10, 0.12 for PM2.5, 6.4 for SO2, and 2.0 for CO, while those of the BB-coal were 0.30 for PM10, 0.094 for PM2.5, 2.4 for SO2, and 1.7 for CO. PM10 and PM2.5 elemental compositions are also presented for both types of coal tested in the study.

Boiler Briquette Coal versus Raw Coal: Part I-Stack Gas Emissions.

Science.gov (United States)

Ge, Su; Bai, Zhipeng; Liu, Weili; Zhu, Tan; Wang, Tongjian; Qing, Sheng; Zhang, Junfeng

2001-04-01

Stack gas emissions were characterized for a steam-generating boiler commonly used in China. The boiler was tested when fired with a newly formulated boiler briquette coal (BB-coal) and when fired with conventional raw coal (R-coal). The stack gas emissions were analyzed to determine emission rates and emission factors and to develop chemical source profiles. A dilution source sampling system was used to collect PM on both Teflon membrane filters and quartz fiber filters. The Teflon filters were analyzed gravimetrically for PM 10 and PM 2.5 mass concentrations and by X-ray fluorescence (XRF) for trace elements. The quartz fiber filters were analyzed for organic carbon (OC) and elemental carbon (EC) using a thermal/optical reflectance technique. Sulfur dioxide was measured using the standard wet chemistry method. Carbon monoxide was measured using an Orsat combustion analyzer. The emission rates of the R-coal combustion (in kg/hr), determined using the measured stack gas concentrations and the stack gas emission rates, were 0.74 for PM 10 , 0.38 for PM 25 , 20.7 for SO 2 , and 6.8 for CO, while those of the BB-coal combustion were 0.95 for PM 10 , 0.30 for PM 2 5 , 7.5 for SO 2 , and 5.3 for CO. The fuel-mass-based emission factors (in g/kg) of the R-coal, determined using the emission rates and the fuel burn rates, were 1.68 for PM 10 , 0.87 for PM 25 , 46.7 for SO 2 , and 15 for CO, while those of the BB-coal were 2.51 for PM 10 , 0.79 for PM 2.5 , 19.9 for SO 2 , and 14 for CO. The task-based emission factors (in g/ton steam generated) of the R-coal, determined using the fuel-mass-based emission factors and the coal/ steam conversion factors, were 0.23 for PM 10 , 0.12 for PM 2.5 , 6.4 for SO 2 , and 2.0 for CO, while those of the BB-coal were 0.30 for PM 10 , 0.094 for PM 2.5 , 2.4 for SO 2 , and 1.7 for CO. PM 10 and PM 2.5 elemental compositions are also presented for both types of coal tested in the study.

Shale gas vs. coal: Policy implications from environmental impact comparisons of shale gas, conventional gas, and coal on air, water, and land in the United States

International Nuclear Information System (INIS)

Jenner, Steffen; Lamadrid, Alberto J.

2013-01-01

The aim of this paper is to examine the major environmental impacts of shale gas, conventional gas and coal on air, water, and land in the United States. These factors decisively affect the quality of life (public health and safety) as well as local and global environmental protection. Comparing various lifecycle assessments, this paper will suggest that a shift from coal to shale gas would benefit public health, the safety of workers, local environmental protection, water consumption, and the land surface. Most likely, shale gas also comes with a smaller GHG footprint than coal. However, shale gas extraction can affect water safety. This paper also discusses related aspects that exemplify how shale gas can be more beneficial in the short and long term. First, there are technical solutions readily available to fix the most crucial problems of shale gas extraction, such as methane leakages and other geo-hazards. Second, shale gas is best equipped to smoothen the transition to an age of renewable energy. Finally, this paper will recommend hybrid policy regulations. - Highlights: ► We examine the impacts of (un)conventional gas and coal on air, water, and land. ► A shift from coal to shale gas would benefit public health. ► Shale gas extraction can affect water safety. ► We discuss technical solutions to fix the most crucial problems of shale gas extraction. ► We recommend hybrid regulations.

Technical review of coal gasifiers for production of synthetic natural gas

International Nuclear Information System (INIS)

Lee, Geun Woo; Shin, Yong Seung

2012-01-01

Because of the increasing cost of oil and natural gas, energy production technologies using coal, including synthetic natural gas (SNG) and integrated gasification combined cycle (IGCC), have attracted attention because of the relatively low cost of coal. During the early stage of a project, the developer or project owner has many options with regard to the selection of a gasifier. In particular, from the viewpoint of feasibility, the gasifier is a key factor in the economic evaluation. This study compares the technical aspects of gasifiers for a real SNG production project in an early stage. A fixed bed slagging gasifier, wet type entrained gasifier, and dry type entrained gasifier, all of which have specific advantages, can be used for the SNG production project. Base on a comparison of the process descriptions and performances of each gasifier, this study presents a selection guideline for a gasifier for an SNG production project that will be beneficial to project developers and EPC (Engineering, Procurement, Construction) contractors

Probabilistic Analysis of Electrical Energy Costs: Comparing Production Costs for Gas, Coal and Nuclear Power Plants. Annex III

Energy Technology Data Exchange (ETDEWEB)

NONE

2013-12-15

The increase in electricity demand is linked to the development of the economy and living standards in each country. This is especially true in those developing countries in which electricity consumption is far below the average of industrialized countries. To satisfy the increased demand for electricity, it is necessary to build new electrical power plants that could, in an optimum way, meet the imposed acceptability criteria. The main criteria are the potential to supply the required energy and to supply it with minimum or, at least, acceptable costs and environmental impacts, to satisfy the licensing requirements and be acceptable to the public. The main competitors for electricity production in the next few decades are fossil fuel power plants (coal and gas) and nuclear power plants. Power plants making use of renewables (solar, wind, biomass) are also important, but due to limited energy supply potential and high costs, can only be a supplement to the main generating units. Large hydropower plants would be competitive under the condition that suitable sites for the construction of such plants exist. Unfortunately, both in Croatia and in the rest of central Europe, such sites are scarce.

Competition between coal and gas for large scale power generation

International Nuclear Information System (INIS)

Howieson, B.

1997-01-01

The relative competitiveness of coal- and gas-fired generation will be affected by distinctive country and market factors as well as site specific considerations, regarding such factors as environment, market structure and economics (such as fuel and plant costs). National and international politics have an impact on all three factors and any decision on the development of generation plant must take into account both current and future political climates. An analysis suggests that, at the present time, upgrading existing coal stations is attractive compared with new combined cycle gas turbines (CCGTs). However, this conclusion is highly dependent on the site specific nature of existing plant and the anticipated future environmental regime. Increased environmental pressure, particularly in the area of CO 2 emissions, would result in CCGTs being the first choice plant option. (R.P.)

Cost comparison of 4x500 MW coal-fuelled and 4x850 MW CANDU nuclear generating stations

International Nuclear Information System (INIS)

Costa, M.

1981-01-01

The lifetime costs for a 4x850 MW CANDU generating station are compared to those for 4x500 MW bituminous coal-fuelled generating stations. Two types of coal-fuelled stations are considered; one burning U.S. coal which includes flue gas desulfurization and one burning Western Canadian coal. Current estimates for the capital costs, operation and maintenance costs, fuel costs, decommissioning costs and irradiated fuel management costs are shown. The results show: (1) The accumulated discounted costs of nuclear generation, although initially higher, are lower than coal-fuelled generation after two or three years. (2) Fuel costs provide the major contribution to the total lifetime costs for coal-fuelled stations whereas capital costs are the major item for the nuclear station. (3) The break even lifetime capacity factor between nuclear and U.S. coal-fuelled generation is projected to be 5%; that for nuclear and Canadian coal-fuelled generation is projected to be 9%. (4) Large variations in the costs are required before the cost advantage of nuclear generation is lost. (5) Comparison with previous results shows that the nuclear alternative has a greater cost advantage in the current assessment. (6) The total unit energy cost remains approximately constant throughout the station life for nuclear generation while that for coal-fuelled generation increases significantly due to escalating fuel costs. The 1978 and 1979 actual total unit energy cost to the consumer for several Ontario Hydro stations are detailed, and projected total unit energy costs for several Ontario Hydro stations are shown in terms of escalated dollars and in 1980 constant dollars

Nuclear vs coal: comparing cost trends

International Nuclear Information System (INIS)

Harrer, B.; Nieves, L.

1981-01-01

The leading competitors in the new-capacity-addition options, from now to 1990, will be nuclear and coal-fired units. As an alternative viewpoint to the coal vs nuclear economic comparison presented in the October 1981 issue of Electrical World, this study represents an analysis of cost data for generating electricity from the two fuel sources. The economic impacts on nuclear and coal units of varying the levels of several key cost parameters are examined and analyzed. 13 figures

Target costing as an element of the hard coal extraction cost planning process

Directory of Open Access Journals (Sweden)

Katarzyna Segeth-Boniecka

2017-09-01

Full Text Available Target costing as an element of the hard coal extraction cost planning process Striving for the efficiency of activities is of great significance in the management of hard coal extractive enterprises, which are constantly subjected to the process of restructuring. Effective cost management is an important condition of the increase in the efficiency of the researched business entities’ activity. One of the tools whose basic objective is conscious influencing cost levels is target costing. The aim of this article is to analyse the conditions of implementing target costing in the planning of hard coal extraction costs in hard coal mines in Poland. The subject area raises a topical and important problem of the scope of solutions concerning cost analysis in hard coal mines in Poland, which has not been thoroughly researched yet. To achieve the abovementioned aim, the theoretical works of the subject area have been referenced. The mine management process is difficult and requires the application of best suited and most modern tools, including those used in the planning process of hard coal extraction costs in order to support the economic efficiency of mining operations. The use of the target costing concept in the planning of hard coal mine operations aims to support the decision-making process, so as to achieve a specified level of economic efficiency of the operations carried out in a territorially designated site of hard coal extraction.

Total generating costs: coal and nuclear plants

International Nuclear Information System (INIS)

1979-02-01

The study was confined to single and multi-unit coal- and nuclear-fueled electric-generating stations. The stations are composed of 1200-MWe PWRs; 1200-MWe BWRs; 800-and 1200-MWe High-Sulfur Coal units, and 800- and 1200-MWe Low-Sulfur Coal units. The total generating cost estimates were developed for commercial operation dates of 1985 and 1990; for 5 and 8% escalation rates, for 10 and 12% discount rates; and, for capacity factors of 50, 60, 70, and 80%. The report describes the methodology for obtaining annualized capital costs, levelized coal and nuclear fuel costs, levelized operation and maintenance costs, and the resulting total generating costs for each type of station. The costs are applicable to a hypothetical Middletwon site in the Northeastern United States. Plant descriptions with general design parameters are included. The report also reprints for convenience, summaries of capital cost by account type developed in the previous commercial electric-power cost studies. Appropriate references are given for additional detailed information. Sufficient detail is given to allow the reader to develop total generating costs for other cases or conditions

Clean utilization of low-rank coals for low-cost power generation

International Nuclear Information System (INIS)

Sondreal, E.A.

1992-01-01

Despite the unique utilization problems of low-rank coals, the ten US steam electric plants having the lowest operating cost in 1990 were all fueled on either lignite or subbituminous coal. Ash deposition problems, which have been a major barrier to sustaining high load on US boilers burning high-sodium low-rank coals, have been substantially reduced by improvements in coal selection, boiler design, on-line cleaning, operating conditions, and additives. Advantages of low-rank coals in advanced systems are their noncaking behavior when heated, their high reactivity allowing more complete reaction at lower temperatures, and the low sulfur content of selected deposits. The principal barrier issues are the high-temperature behavior of ash and volatile alkali derived from the coal-bound sodium found in some low-rank coals. Successful upgrading of low-rank coals requires that the product be both stable and suitable for end use in conventional and advanced systems. Coal-water fuel produced by hydrothermal processing of high-moisture low-rank coal meets these criteria, whereas most dry products from drying or carbonizing in hot gas tend to create dust and spontaneous ignition problems unless coated, agglomerated, briquetted, or afforded special handling

Advanced design nuclear power plants: Competitive, economical electricity. An analysis of the cost of electricity from coal, gas and nuclear power plants

International Nuclear Information System (INIS)

1992-06-01

This report presents an updated analysis of the projected cost of electricity from new baseload power plants beginning operation around the year 2000. Included in the study are: (1) advanced-design, standardized nuclear power plants; (2) low emissions coal-fired power plants; (3) gasified coal-fired power plants; and (4) natural gas-fired power plants. This analysis shows that electricity from advanced-design, standardized nuclear power plants will be economically competitive with all other baseload electric generating system alternatives. This does not mean that any one source of electric power is always preferable to another. Rather, what this analysis indicates is that, as utilities and others begin planning for future baseload power plants, advanced-design nuclear plants should be considered an economically viable option to be included in their detailed studies of alternatives. Even with aggressive and successful conservation, efficiency and demand-side management programs, some new baseload electric supply will be needed during the 1990s and into the future. The baseload generating plants required in the 1990s are currently being designed and constructed. For those required shortly after 2000, the planning and alternatives assessment process must start now. It takes up to ten years to plan, design, license and construct a new coal-fired or nuclear fueled baseload electric generating plant and about six years for a natural gas-fired plant. This study indicates that for 600-megawatt blocks of capacity, advanced-design nuclear plants could supply electricity at an average of 4.5 cents per kilowatt-hour versus 4.8 cents per kilowatt-hour for an advanced pulverized-coal plant, 5.0 cents per kilowatt-hour for a gasified-coal combined cycle plant, and 4.3 cents per kilowatt-hour for a gas-fired combined cycle combustion turbine plant

Synthetic natural gas in California: When and why. [from coal

Science.gov (United States)

Wood, W. B.

1978-01-01

A coal gasification plant planned for northwestern New Mexico to produce 250 MMCFD of pipeline quality gas (SNG) using the German Lurgi process is discussed. The SNG will be commingled with natural gas in existing pipelines for delivery to southern California and the Midwest. Cost of the plant is figured at more than $1.4 billion in January 1978 dollars with a current inflation rate of $255,000 for each day of delay. Plant start-up is now scheduled for 1984.

Next Generation Pressurized Oxy-Coal Combustion: High Efficiency and No Flue Gas Recirculation

Energy Technology Data Exchange (ETDEWEB)

Rue, David

2013-09-30

The Gas Technology Institute (GTI) has developed a pressurized oxy-coal fired molten bed boiler (MBB) concept, in which coal and oxygen are fired directly into a bed of molten coal slag through burners located on the bottom of the boiler and fired upward. Circulation of heat by the molten slag eliminates the need for a flue gas recirculation loop and provides excellent heat transfer to steam tubes in the boiler walls. Advantages of the MBB technology over other boilers include higher efficiency (from eliminating flue gas recirculation), a smaller and less expensive boiler, modular design leading to direct scalability, decreased fines carryover and handling costs, smaller exhaust duct size, and smaller emissions control equipment sizes. The objective of this project was to conduct techno-economic analyses and an engineering design of the MBB project and to support this work with thermodynamic analyses and oxy-coal burner testing. Techno-economic analyses of GTI’s pressurized oxy-coal fired MBB technology found that the overall plant with compressed CO2 has an efficiency of 31.6%. This is a significant increase over calculated 29.2% efficiency of first generation oxy-coal plants. Cost of electricity (COE) for the pressurized MBB supercritical steam power plant with CO2 capture and compression was calculated to be 134% of the COE for an air-coal supercritical steam power plant with no CO2 capture. This compares positively with a calculated COE for first generation oxy-coal supercritical steam power plants with CO2 capture and compression of 164%. The COE for the MBB power plant is found to meet the U.S. Department of Energy (DOE) target of 135%, before any plant optimization. The MBB power plant was also determined to be simpler than other oxy-coal power plants with a 17% lower capital cost. No other known combustion technology can produce higher efficiencies or lower COE when CO2 capture and compression are included. A thermodynamic enthalpy and exergy analysis

Automated cost modeling for coal combustion systems

International Nuclear Information System (INIS)

Rowe, R.M.; Anast, K.R.

1991-01-01

This paper reports on cost information developed at AMAX R and D Center for coal-water slurry production implemented in an automated spreadsheet (Lotus 123) for personal computer use. The spreadsheet format allows the user toe valuate impacts of various process options, coal feedstock characteristics, fuel characteristics, plant location sites, and plant sizes on fuel cost. Model flexibility reduces time and labor required to determine fuel costs and provides a basis to compare fuels manufactured by different processes. The model input includes coal characteristics, plant flowsheet definition, plant size, and market location. Based on these inputs, selected unit operations are chosen for coal processing

Greenhouse gas emission from Australian coal mining

International Nuclear Information System (INIS)

Williams, D.

1998-01-01

Since 1997, when the Australian Coal Association (ACA) signed a letter of Intent in respect of the governments Greenhouse Challenge Program, it has encouraged its member companies to participate. Earlier this year, the ACA commissioned an independent scoping study on greenhouse gas emissions in the black coal mining industry This was to provide background information, including identification of information gaps and R and D needs, to guide the formulation of a strategy for the mitigation of greenhouse gas emissions associated with the mining, processing and handling of black coals in Australia. A first step in the process of reducing emission levels is an appreciation of the source, quantity and type of emissions om nine sites. It is shown that greenhouse gas emissions on mine sites come from five sources: energy consumption during mining activities, the coal seam gas liberated due to the extraction process i.e. fugitive emissions, oxidation of carbonaceous wastes, land use, and embodied energy. Also listed are indications of the degree of uncertainty associated with each of the estimates

Small-medium sized nuclear coal and gas power plant: A probabilistic analysis of their financial performances and influence of CO2 cost

International Nuclear Information System (INIS)

Locatelli, Giorgio; Mancini, Mauro

2010-01-01

Nations or regions with limited electrical grid and restricted financial resources are a suitable market for small medium power plants with a size of 300-400 MWe. The literature presents several comparisons about the economics of large power plants (of about 1000 MWe); however there are not probabilistic analysis regarding the economics of small medium power plants. This paper fills this gap comparing, with a Monte Carlo evaluation, the economical and financial performances of a nuclear reactor, a coal fired power plant and a combined cycle gas turbine (CCGT) of 335 MWe. The paper aims also to investigate the effect of the carbon tax and electrical energy price on the economics of these plants. The analysis show as, without any carbon tax, the coal plant has the lowest levelised unit electricity cost (LUEC) and the highest net present value (NPV). Introducing the carbon tax the rank changes: depending on its amount the first and the nuclear after becomes the plant with lower LUEC and highest NPV. Therefore, the uncertainty in the carbon tax cost increases the risk of investing in a coal plant above the level of the new small medium reactor.

Microbial production of natural gas from coal and organic-rich shale

Science.gov (United States)

Orem, William

2013-01-01

Natural gas is an important component of the energy mix in the United States, producing greater energy yield per unit weight and less pollution compared to coal and oil. Most of the world’s natural gas resource is thermogenic, produced in the geologic environment over time by high temperature and pressure within deposits of oil, coal, and shale. About 20 percent of the natural gas resource, however, is produced by microorganisms (microbes). Microbes potentially could be used to generate economic quantities of natural gas from otherwise unexploitable coal and shale deposits, from coal and shale from which natural gas has already been recovered, and from waste material such as coal slurry. Little is known, however, about the microbial production of natural gas from coal and shale.

The Clean Coal Technology Program 100 MWe demonstration of gas suspension absorption for flue gas desulfurization

Energy Technology Data Exchange (ETDEWEB)

Hsu, F.E.; Hedenhag, J.G. [AirPol Inc., Teterboro, NJ (United States); Marchant, S.K.; Pukanic, G.W. [Dept. of Energy, Pittsburgh, PA (United States). Pittsburgh Energy Technology Center; Norwood, V.M.; Burnett, T.A. [Tennessee Valley Authority, Chattanooga, TN (United States)

1997-12-31

AirPol Inc., with the cooperation of the Tennessee Valley Authority (TVA) under a Cooperative Agreement with the United States Department of Energy, installed and tested a 10 MWe Gas Suspension Absorption (GSA) Demonstration system at TVA`s Shawnee Fossil Plant near Paducah, Kentucky. This low-cost retrofit project demonstrated that the GSA system can remove more than 90% of the sulfur dioxide from high-sulfur coal-fired flue gas, while achieving a relatively high utilization of reagent lime. This paper presents a detailed technical description of the Clean Coal Technology demonstration project. Test results and data analysis from the preliminary testing, factorial tests, air toxics texts, 28-day continuous demonstration run of GSA/electrostatic precipitator (ESP), and 14-day continuous demonstration run of GSA/pulse jet baghouse (PJBH) are also discussed within this paper.

Gas distributor for fluidized bed coal gasifier

Science.gov (United States)

Worley, Arthur C.; Zboray, James A.

1980-01-01

A gas distributor for distributing high temperature reaction gases to a fluidized bed of coal particles in a coal gasification process. The distributor includes a pipe with a refractory reinforced lining and a plurality of openings in the lining through which gas is fed into the bed. These feed openings have an expanding tapered shape in the downstream or exhaust direction which aids in reducing the velocity of the gas jets as they enter the bed.

Membrane Process to Capture CO{sub 2} from Coal-Fired Power Plant Flue Gas

Energy Technology Data Exchange (ETDEWEB)

Merkel, Tim; Wei, Xiaotong; Firat, Bilgen; He, Jenny; Amo, Karl; Pande, Saurabh; Baker, Richard; Wijmans, Hans; Bhown, Abhoyjit

2012-03-31

This final report describes work conducted for the U.S. Department of Energy National Energy Technology Laboratory (DOE NETL) on development of an efficient membrane process to capture carbon dioxide (CO{sub 2}) from power plant flue gas (award number DE-NT0005312). The primary goal of this research program was to demonstrate, in a field test, the ability of a membrane process to capture up to 90% of CO{sub 2} in coal-fired flue gas, and to evaluate the potential of a full-scale version of the process to perform this separation with less than a 35% increase in the levelized cost of electricity (LCOE). Membrane Technology and Research (MTR) conducted this project in collaboration with Arizona Public Services (APS), who hosted a membrane field test at their Cholla coal-fired power plant, and the Electric Power Research Institute (EPRI) and WorleyParsons (WP), who performed a comparative cost analysis of the proposed membrane CO{sub 2} capture process. The work conducted for this project included membrane and module development, slipstream testing of commercial-sized modules with natural gas and coal-fired flue gas, process design optimization, and a detailed systems and cost analysis of a membrane retrofit to a commercial power plant. The Polaris? membrane developed over a number of years by MTR represents a step-change improvement in CO{sub 2} permeance compared to previous commercial CO{sub 2}-selective membranes. During this project, membrane optimization work resulted in a further doubling of the CO{sub 2} permeance of Polaris membrane while maintaining the CO{sub 2}/N{sub 2} selectivity. This is an important accomplishment because increased CO{sub 2} permeance directly impacts the membrane skid cost and footprint: a doubling of CO{sub 2} permeance halves the skid cost and footprint. In addition to providing high CO{sub 2} permeance, flue gas CO{sub 2} capture membranes must be stable in the presence of contaminants including SO{sub 2}. Laboratory tests showed no

Process for the gas extraction of coal

Energy Technology Data Exchange (ETDEWEB)

Urquhart, D B

1976-05-20

The object of the invention is a process for the hydroextraction of coal is treated with water and carbon monoxide at a temperature in the region of 300 - 380/sup 0/C. After treatment is completed, the gases are separated from the treated gas; the treated coal is then extracted with an extraction medium during the gas phase at a temperature of at least 400/sup 0/C, the remainder is separated from the gas phase and the coal extract is obtained from the extraction medium. Hydrogenation is preferably carried out at a temperature in the region of 320 - 370/sup 0/C and at a pressure of 200 - 400 at. The time required for treatment with carbon monoxide and water is 1/4 - 2 hours, and in special cases 3/4 - 1 1/2 hours. The coal material itself is nutty slack, of which more than 95% of the coal particles pass through a 1.5 mm mesh sieve. After the hydrogenation the extraction is carried out at a temperature in the region of 400 - 450/sup 0/C. The patent claims relate to the types of extraction media used.

Solid-Gas Coupling Model for Coal-Rock Mass Deformation and Pressure Relief Gas Flow in Protection Layer Mining

OpenAIRE

Zhu, Zhuohui; Feng, Tao; Yuan, Zhigang; Xie, Donghai; Chen, Wei

2018-01-01

The solid-gas coupling model for mining coal-rock mass deformation and pressure relief gas flow in protection layer mining is the key to determine deformation of coal-rock mass and migration law of pressure relief gas of protection layer mining in outburst coal seams. Based on the physical coupling process between coal-rock mass deformation and pressure-relief gas migration, the coupling variable of mining coal-rock mass, a part of governing equations of gas seepage field and deformation fiel...

Historical costs of coal-fired electricity and implications for the future

International Nuclear Information System (INIS)

McNerney, James; Doyne Farmer, J.; Trancik, Jessika E.

2011-01-01

We study the cost of coal-fired electricity in the United States between 1882 and 2006 by decomposing it in terms of the price of coal, transportation cost, energy density, thermal efficiency, plant construction cost, interest rate, capacity factor, and operations and maintenance cost. The dominant determinants of cost have been the price of coal and plant construction cost. The price of coal appears to fluctuate more or less randomly while the construction cost follows long-term trends, decreasing from 1902 to 1970, increasing from 1970 to 1990, and leveling off since then. Our analysis emphasizes the importance of using long time series and comparing electricity generation technologies using decomposed total costs, rather than costs of single components like capital. By taking this approach we find that the history of coal-fired electricity suggests there is a fluctuating floor to its future costs, which is determined by coal prices. Even if construction costs resumed a decreasing trend, the cost of coal-based electricity would drop for a while but eventually be determined by the price of coal, which fluctuates while showing no long-term trend. - Research highlights: → 125-year history highlights the dominant determinants of coal-fired electricity costs. → Results suggest a fluctuating floor to future costs, determined by coal prices. → Analysis emphasizes importance of comparing technologies using decomposed total costs.

Ten questions on the future of coal

International Nuclear Information System (INIS)

Ruelle, G.

2005-01-01

The author comments data and information on the main uses of coal, the evolution of the coal share in the world energy consumption, the amounts and locations of coal reserves in comparison with oil and gas, the coal reserves left in the European Union, the world coal market characteristics with respect to those of oil and gas, the reason of the bad environmental reputation of coal, the internal cost of a KWh produced by a coal power station, the external cost resulting from its environmental pollution, the possibility of reducing those defects by 2020, 2040, 2060, the way of transforming coal into oil and to which cost, in order to expand its use to modern transports, the role of coal during the 21. century and the possibilities of CO 2 sequestration

Geochemical characteristics of Carboniferous-Permian coal-formed gas in Bohai Bay Basin

Energy Technology Data Exchange (ETDEWEB)

Shipeng Huang; Fengrong Liao; Xiaoqi Wu [PetroChina, Beijing (China). Research Institute of Petroleum Exploration & Development

2010-03-15

Coal-formed gas reservoirs have been found in several depressions in Bohai Bay Basin. The gas was mainly generated by the Carboniferous-Permian coal measures, which are good source rocks. The exploration of coal-formed gas has a broad prospect. The main reservoirs of the coal-formed gas are Ordovician, Carboniferous-Permian, and Paleogene stratum. Coal-formed gas in the Bohai Bay Basin is chiefly composed of hydrocarbon gases. The percentage content of carbon dioxide is more than that of the nitrogen gas. The stable carbon isotope values of the hydrocarbon gases of different depressions and different reservoirs usually reversed. The reversed values of gas samples account for 52.1% of all the samples. Reversion values of the carbon isotope are mainly because of the mixing of gases from same source rocks but with different maturity. Among the three main reservoirs, coal-formed gas preserved in Paleogene stratum has the heaviest carbon isotope, the second is the gas in Carboniferous-Permian stratum, and the Ordovician gas possesses the lightest carbon isotope. Based on the analysis of the characteristics of carbon isotope of hydrocarbon gases in well Qishen-1 and the distribution of the Carboniferous-Permian coal measures, the gas of the well is derived from the high-matured Carboniferous-Permian coal measures.

A study on the reduction in the production cost of the long-running collieries and mechanization of coal mining

Energy Technology Data Exchange (ETDEWEB)

Kim, Young Shik; Hong, Jee Sang; Lee, Kyung Woon; Kim, Oak Hwan; Kim, Dae Kyung [Korea Inst. of Geology Mining and Materials, Taejon (Korea, Republic of)

1995-12-01

The reducing coal market has been enforcing the coal industry to make exceptional rationalization and restructuring efforts since the end of the eighties. To the competition from crude oil and natural gas has been added the growing pressure from rising wages and production cost. To improve the competitive position of the coal mines against oil and gas through cost reduction, studies on mining technology have been carried out. Investigations and analyses on the technologies used in Hanbo Colliery which was designated one of the long term running mines were done and recommendations were made. And also a site test of plough were implemented at the KyungDong Colliery. The mechanization program of 1994 were analyzed and evaluated separately. (author). 38 refs.

Problems of coal-based power generation

International Nuclear Information System (INIS)

Noskievic, P.

1996-01-01

Current problems of and future trends in coal-based power generation are discussed. The present situation is as follows: coal, oil and gas contribute to world fossil fuel resources 75%, 14%, and 11%, respectively, and if the current trend will continue, will be depleted in 240, 50, and 60 years, respectively; the maximum resource estimates (including resources that have not yet been discovered) are 50% higher for oil and 100% higher for gas, for coal such estimates have not been made. While the world prices of coal are expected to remain virtually constant, the prices of gas will probably increase to be twice as high in 2010. Thus, the role of coal may be higher in the next century than it is now, provided that due attention is paid to improving the efficiency of coal-fired power plants and reducing their adverse environmental effects. A comparison of economic data for coal-fired and gas-fired power plants is as follows: Investment cost (USD/kW): 1400, 800; fixed running cost (USD/kW.y): 33.67, 9.0; variable running cost (USD/kWh): 0.30, 0.15; power use (kJ/kWh): 10.29, 7.91; annual availability (%): 70, 50; fuel price (USD/GJ): 1.00, 4.30; power price (USD/kWh): 4.28, 5.52. The investment cost for coal-fired plants covers new construction including flue gas purification. The integrated gasification combined cycle (IGCC) seems to be the future of coal-based power generation. The future problems to be addressed include ways to reduce air pollution, improving the efficiency of the gas-steam cycle, and improving the combustion process particularly with a view to reducing substantially its environmental impact. (P.A.). 4 figs., 4 tabs., 9 refs

Coal fired flue gas mercury emission controls

International Nuclear Information System (INIS)

Wu, Jiang; Pan, Weiguo; Cao, Yan; Pan, Weiping

2015-01-01

Mercury (Hg) is one of the most toxic heavy metals, harmful to both the environment and human health. Hg is released into the atmosphere from natural and anthropogenic sources and its emission control has caused much concern. This book introduces readers to Hg pollution from natural and anthropogenic sources and systematically describes coal-fired flue gas mercury emission control in industry, especially from coal-fired power stations. Mercury emission control theory and experimental research are demonstrated, including how elemental mercury is oxidized into oxidized mercury and the effect of flue gas contents on the mercury speciation transformation process. Mercury emission control methods, such as existing APCDs (air pollution control devices) at power stations, sorbent injection, additives in coal combustion and photo-catalytic methods are introduced in detail. Lab-scale, pilot-scale and full-scale experimental studies of sorbent injection conducted by the authors are presented systematically, helping researchers and engineers to understand how this approach reduces the mercury emissions in flue gas and to apply the methods in mercury emission control at coal-fired power stations.

Coal fired flue gas mercury emission controls

Energy Technology Data Exchange (ETDEWEB)

Wu, Jiang; Pan, Weiguo [Shanghai Univ. of Electric Power (China); Cao, Yan; Pan, Weiping [Western Kentucky Univ., Bowling Green, KY (United States)

2015-05-01

Mercury (Hg) is one of the most toxic heavy metals, harmful to both the environment and human health. Hg is released into the atmosphere from natural and anthropogenic sources and its emission control has caused much concern. This book introduces readers to Hg pollution from natural and anthropogenic sources and systematically describes coal-fired flue gas mercury emission control in industry, especially from coal-fired power stations. Mercury emission control theory and experimental research are demonstrated, including how elemental mercury is oxidized into oxidized mercury and the effect of flue gas contents on the mercury speciation transformation process. Mercury emission control methods, such as existing APCDs (air pollution control devices) at power stations, sorbent injection, additives in coal combustion and photo-catalytic methods are introduced in detail. Lab-scale, pilot-scale and full-scale experimental studies of sorbent injection conducted by the authors are presented systematically, helping researchers and engineers to understand how this approach reduces the mercury emissions in flue gas and to apply the methods in mercury emission control at coal-fired power stations.

Commerical electric power cost studies. Capital cost addendum multi-unit coal and nuclear stations

International Nuclear Information System (INIS)

1977-09-01

This report is the culmination of a study performed to develop designs and associated capital cost estimates for multi-unit nuclear and coal commercial electric power stations, and to determine the distribution of these costs among the individual units. This report addresses six different types of 2400 MWe (nominal) multi-unit stations as follows: Two Unit PWR Station-1139 MWe Each, Two Unit BWR Station-1190 MWe Each, Two Unit High Sulfur Coal-Fired Station-1232 MWe Each, Two Unit Low Sulfur Coal-Fired Station-1243 MWe Each, Three Unit High Sulfur Coal-Fired Station-794 MWe Each, Three Unit Low Sulfur Coal-Fired Station-801 MWe Each. Recent capital cost studies performed for ERDA/NRC of single unit nuclear and coal stations are used as the basis for developing the designs and costs of the multi-unit stations. This report includes the major study groundrules, a summary of single and multi-unit stations total base cost estimates, details of cost estimates at the three digit account level and plot plan drawings for each multi-unit station identified

Prevention and forecasting of coal, rock and gas bursts in mines of Donets Coal Basin in USSR

Energy Technology Data Exchange (ETDEWEB)

Swidzinski, A

1977-11-01

Coal and methane bursts as well as sandstone and methane bursts are typical for the Donets Coal Basin. The most effective way of forecasting coal and methane bursts is drilling holes (3.5 m long, 45 mm diameter) and measuring the initial speed of gas outflow (5 litres/min gas outflow is a critical value). Additional parameters in this method are: coal firmness and porosity as well as thickness of coal bed. Forecasting sandstone and gas bursts is based on taking rock samples while drilling. When a sample 1 meter long consists of 30 to 40 so called discs, the danger of outburst is substantial, with the decreasing number of discs the probability of bursts also decreases. The following methods of prevention are used in the Donets Coal Basin: preparatory extraction of a layer protecting another layer below or above, where there is a danger of gas burst. This method is effective in 50% of all cases. Other methods include: filling coal beds with water under high pressure (average norm 25 1 water per 1 m

Feasibility study on recovery and utilization of coal mine gas (CMG) at Donetsk Coal Field

Energy Technology Data Exchange (ETDEWEB)

NONE

2001-03-01

For the purpose of getting petroleum substitution energy and reducing greenhouse effect gas emission, an investigational study was carried out of the project for methane gas recovery/utilization at the Donbassa coal mine in Ukraine. At the Donbassa coal mine, degassing by test boring is being conducted to reduce the gas emission at coal face for safety, but most of the gas is discharged into the air. In this project, the following were studied: degassing boring/gas induction from bore hole/measurement in gas induction pipe, gas recovery system combined with gas induction in flyash, and installation/operation of gas engine power generation facilities (1,710kW x 7 units) with exhaust heat recovery boiler using the recovered methane gas as fuel. The results obtained were the petroleum substitution amount of 31,000 toe/y and the amount of greenhouse effect gas reduction of 480,000 t/y. In the economical estimation, the initial investment amount was 3 billion yen, the profitability of the total investment used was 2.9%, and the internal earning rate was 6.5%. (NEDO)

Clean coal and heavy oil technologies for gas turbines

Energy Technology Data Exchange (ETDEWEB)

Todd, D.M. [GE Industrial & Power Systems, Schenectady, NY (United States)

1994-12-31

Global power generation markets have shown a steady penetration of GT/CC technology into oil and gas fired applications as the technology has matured. The lower cost, improved reliability and efficiency advantages of combined cycles can now be used to improve the cost of electricity and environmental acceptance of poor quality fuels such as coal, heavy oil, petroleum coke and waste products. Four different technologies have been proposed, including slagging combustors, Pressurized Fluidized Bed Combustion (PFBC), Externally Fired Combined Cycle (EFCC) and Integrated Gasification Combined Cycle (IGCC). Details of the technology for the three experimental technologies can be found in the appendix. IGCC is now a commercial technology. In the global marketplace, this shift is being demonstrated using various gasification technologies to produce a clean fuel for the combined cycle. Early plants in the 1980s demonstrated the technical/environmental features and suitability for power generation plants. Economics, however, were disappointing until the model F GT technologies were first used commercially in 1990. The economic break-through of matching F technology gas turbines with gasification was not apparent until 1993 when a number of projects were ordered for commercial operation in the mid-1990s. GE has started 10 new projects for operation before the year 2000. These applications utilize seven different gasification technologies to meet specific application needs. Early plants are utilizing low-cost fuels, such as heavy oil or petroleum coke, to provide economics in first-of-a-kind plants. Some special funding incentives have broadened the applications to include power-only coal plants. Next generation gas turbines projected for commercial applications after the year 2000 will contribute to another step change in technology. It is expected that the initial commercialization process will provide the basis for clear technology choices on future plants.

Solar coal gasification reactor with pyrolysis gas recycle

Science.gov (United States)

Aiman, William R.; Gregg, David W.

1983-01-01

Coal (or other carbonaceous matter, such as biomass) is converted into a duct gas that is substantially free from hydrocarbons. The coal is fed into a solar reactor (10), and solar energy (20) is directed into the reactor onto coal char, creating a gasification front (16) and a pyrolysis front (12). A gasification zone (32) is produced well above the coal level within the reactor. A pyrolysis zone (34) is produced immediately above the coal level. Steam (18), injected into the reactor adjacent to the gasification zone (32), reacts with char to generate product gases. Solar energy supplies the energy for the endothermic steam-char reaction. The hot product gases (38) flow from the gasification zone (32) to the pyrolysis zone (34) to generate hot char. Gases (38) are withdrawn from the pyrolysis zone (34) and reinjected into the region of the reactor adjacent the gasification zone (32). This eliminates hydrocarbons in the gas by steam reformation on the hot char. The product gas (14) is withdrawn from a region of the reactor between the gasification zone (32) and the pyrolysis zone (34). The product gas will be free of tar and other hydrocarbons, and thus be suitable for use in many processes.

Electricity and fluid fuels from biomass and coal using advanced technologies: a cost comparison for developing country applications

Energy Technology Data Exchange (ETDEWEB)

Kartha, S; Larson, E D; Williams, R H [Center for Energy and Environment Studies School of Engineering and Applied Science, Princeton University, Princeton, NJ (United States); Katofsky, R E [Arthur D. Little Co., Cambridge, MA (United States); Chen, J [Thermo Fibertek, Inc., Auburn, MA (United States); Marrison, C I [Oliver, Wyman and Co., New York, NY (United States)

1995-12-01

Recent analyses of alternative global energy supply strategies, such as the forthcoming report of the Intergovernmental Panel on Climate Change (IPCC), to be published in 1996, have drawn attention to the possibility that biomass modernized with advanced technologies could play an important role in meeting global energy needs in the next century. This paper discusses two promising classes of advanced technologies that offer the potential for providing modem energy carriers (electricity and fluid fuels) from biomass at competitive costs within one or two decades. These technologies offer significantly more efficient use of land than currently commercial technologies for producing electricity and fluid fuels from biomass, as well as substantially improved energy balances. Electricity is Rely to be the first large market for modernized biomass, but the potential market for fluid fuel production is likely to be much larger. As coal is likely to present a more serious competitive challenge to biomass in the long run, we present an economic comparison with coal-based electricity and fluid fuels. A meaningful economic comparison between coal and biomass is possible because these feedstocks are sufficiently alike in their physical characteristics that similar conversion technologies may well be used for producing electricity and fluid fuels from them. When similar conversion technologies are used for both feedstocks, the relative costs of electricity or fluid fuels will be determined by the distinguishing technical characteristics of the feedstocks (sulphur content, moisture content and reactivity) and by the relative feedstock prices. Electric power generation from biomass and coal are compared here using an advanced integrated gasifier/gas turbine cycle that offers the potential for achieving high efficiency, low unit capital cost and low local pollutant emissions: the steam-injected gas turbine coupled to an air-blown gasifier. For both feedstocks, generation costs are

Electricity and fluid fuels from biomass and coal using advanced technologies: a cost comparison for developing country applications

International Nuclear Information System (INIS)

Kartha, S.; Larson, E.D.; Williams, R.H.; Katofsky, R.E.; Chen, J.; Marrison, C.I.

1995-01-01

Recent analyses of alternative global energy supply strategies, such as the forthcoming report of the Intergovernmental Panel on Climate Change (IPCC), to be published in 1996, have drawn attention to the possibility that biomass modernized with advanced technologies could play an important role in meeting global energy needs in the next century. This paper discusses two promising classes of advanced technologies that offer the potential for providing modem energy carriers (electricity and fluid fuels) from biomass at competitive costs within one or two decades. These technologies offer significantly more efficient use of land than currently commercial technologies for producing electricity and fluid fuels from biomass, as well as substantially improved energy balances. Electricity is Rely to be the first large market for modernized biomass, but the potential market for fluid fuel production is likely to be much larger. As coal is likely to present a more serious competitive challenge to biomass in the long run, we present an economic comparison with coal-based electricity and fluid fuels. A meaningful economic comparison between coal and biomass is possible because these feedstocks are sufficiently alike in their physical characteristics that similar conversion technologies may well be used for producing electricity and fluid fuels from them. When similar conversion technologies are used for both feedstocks, the relative costs of electricity or fluid fuels will be determined by the distinguishing technical characteristics of the feedstocks (sulphur content, moisture content and reactivity) and by the relative feedstock prices. Electric power generation from biomass and coal are compared here using an advanced integrated gasifier/gas turbine cycle that offers the potential for achieving high efficiency, low unit capital cost and low local pollutant emissions: the steam-injected gas turbine coupled to an air-blown gasifier. For both feedstocks, generation costs are

Coal seam gas-supply and impact on U.S. markets and Canadian producers

International Nuclear Information System (INIS)

Kelafant, J.

1992-01-01

The basic ways in which coalbed methane differs from natural gas are described. Coalbed methane is stored at a higher capacity in the coal seam, has a different production curve, and exploration costs are lower. Comparing a conventional gas well having 2 billion ft 3 reserves with coalbed methane wells in the San Juan and Warrior basins, gas from the conventional well costs $1.90 per 1,000 ft 3 and methane from the San Juan and Warrior wells costs $1.50 and $2.40 per 1,000 ft 3 respectively. A 90 cent per 1,000 ft 3 tax credit on coalbed methane reduces the two latter costs significantly and is without doubt the driving force behind the coalbed methane industry in some areas. Examples from the Warrior and San Juan basins are described to illustrate the technology driven economics of coalbed methane. Substantial improvements in gas production can be achieved by such means as multiple seam completion technologies, improved well stimulation, optimum well spacing, and the use of cavitation completion. Technically recoverable coalbed methane resources in the USA are estimated at 145 trillion ft 3 , concentrated in the western coal basins. At a wellhead price of $2 per 1,000 ft 3 , the economically recoverable potential is ca 13 trillion ft 3 . Examining future production potential, by developing new technologies or bringing more basins on stream, production could be increased to ca 3 billion ft 3 /d in the late 1990s. It is suggested that the increased volumes of coalbed methane have had minimal impact on gas prices. 9 figs., 12 tabs

The long-term life cycle private and external costs of high coal usage in the US

International Nuclear Information System (INIS)

Bergerson, Joule; Lave, Lester

2007-01-01

Using four times as much coal in 2050 for electricity production need not degrade air quality or increase greenhouse gas emissions. Current SO x and NO x emissions from the power sector could be reduced from 12 to less than 1 and from 5 to 2 million tons annually, respectively, using advanced technology. While direct CO 2 emissions from new power plants could be reduced by over 87%, life cycle emissions could increase by over 25% due to the additional coal that is required to be mined and transported to compensate for the energy penalty of the carbon capture and storage technology. Strict environmental controls push capital costs of pulverized coal (PC) and integrated coal gasification combined cycle (IGCC) plants to $1500-1700/kW and $1600-2000/kW, respectively. Adding carbon capture and storage (CCS) increases costs to $2400-2700/kW and $2100-3000/kW (2005 dollars), respectively. Adding CCS reduces the 40-43% efficiency of the ultra-supercritical PC plant to 31-34%; adding CCS reduces the 32-38% efficiency of the GE IGCC plant to 27-33%. For IGCC, PC, and natural gas combined cycle (NGCC) plants, the carbon dioxide tax would have to be $53, $74, and $61, respectively, to make electricity from a plant with CCS cheaper. Capturing and storing 90% of the CO 2 emissions increases life cycle costs from 5.4 to 11.6 cents/kWh. This analysis shows that 90% CCS removal efficiency, although being a large improvement over current electricity generation emissions, results in life cycle emissions that are large enough that additional effort is required to achieve significant economy-wide reductions in the US for this large increase in electricity generation using either coal or natural gas

Variations in pore characteristics in high volatile bituminous coals: Implications for coal bed gas content

Science.gov (United States)

Mastalerz, Maria; Drobniak, A.; Strapoc, D.; Solano-Acosta, W.; Rupp, J.

2008-01-01

The Seelyville Coal Member of the Linton Formation (Pennsylvanian) in Indiana was studied to: 1) understand variations in pore characteristics within a coal seam at a single location and compare these variations with changes occurring between the same coal at different locations, 2) elaborate on the influence of mineral-matter and maceral composition on mesopore and micropore characteristics, and 3) discuss implications of these variations for coal bed gas content. The coal is high volatile bituminous rank with R0 ranging from 0.57% to 0.60%. BET specific surface areas (determined by nitrogen adsorption) of the coals samples studied range from 1.8 to 22.9??m2/g, BJH adsorption mesopore volumes from 0.0041 to 0.0339??cm3/g, and micropore volumes (determined by carbon dioxide adsorption) from 0.0315 to 0.0540??cm3/g. The coals that had the largest specific surface areas and largest mesopore volumes occur at the shallowest depths, whereas the smallest values for these two parameters occur in the deepest coals. Micropore volumes, in contrast, are not depth-dependent. In the coal samples examined for this study, mineral-matter content influenced both specific surface area as well as mesopore and micropore volumes. It is especially clear in the case of micropores, where an increase in mineral-matter content parallels the decrease of micropore volume of the coal. No obvious relationships were observed between the total vitrinite content and pore characteristics but, after splitting vitrinite into individual macerals, we see that collotelinite influences both meso- and micropore volume positively, whereas collodetrinite contributes to the reduction of mesopore and micropore volumes. There are large variations in gas content within a single coal at a single location. Because of this variability, the entire thickness of the coal must be desorbed in order to determine gas content reliably and to accurately calculate the level of gas saturation. ?? 2008 Elsevier B.V. All

The Late Paleozoic relative gas fields of coal measure in China and their significances on the natural gas industry

Directory of Open Access Journals (Sweden)

Chenchen Fang

2016-12-01

Full Text Available The coal measure gas sources of coal-derived gas fields in the Late Paleozoic China are the Lower Carboniferous Dishuiquan Formation, the Upper Carboniferous Batamayineishan Formation and Benxi Formation, the Lower Permian Taiyuan Formation and Shanxi Formation, and the Upper Permian Longtan Formation. The coal-derived gas accumulates in Ordovician, Carboniferous, Permian, and Paleocene reservoirs and are distributed in Ordos Basin, Bohai Bay Basin, Junggar Basin, and Sichuan Basin. There are 16 gas fields and 12 of them are large gas fields such as the Sulige large gas field which is China's largest reserve with the highest annual output. According to component and alkane carbon isotope data of 99 gas samples, they are distinguished to be coal-derived gas from coal-derived gas with δ13C2 > −28.5‰ and δ13C1 -δ13C2 -δ13C3 identification chart. The Late Paleozoic relative gas fields of coal measure are significant for the Chinese natural gas industry: proven natural gas geological reserves and annual output of them account for 1/3 in China, and the gas source of three significant large gas fields is coal-derived, which of five significant large gas fields supporting China to be a great gas producing country. The average reserves of the gas fields and the large gas fields formed from the late Paleozoic coal measure are 5.3 and 1.7 times that of the gas fields and the large gas fields in China.

Permeability changes in coal resulting from gas desorption. Final report

Energy Technology Data Exchange (ETDEWEB)

Levine, J.R.; Johnson, P.W.

1992-11-30

This report documents studies on the effects of gas sorption on coal, with the intent of eventually evaluating how sorption and strain affect permeability. These studies were, carried out at the University of Alabama during the period from 1989 through 1992. Two major experimental methods were developed and used. In the strain experiments, electronic strain gauges were attached to polished blocks of coal in order to measure linear and volumetric swelling due to gas sorption. The effects of bedding plane orientation, of gas type, and of coal type were investigated. In the gravimetric experiment the weight of small samples of coal was measured during exposure to high pressure gases. Sample measurements were corrected for buoyancy effects and for sample swelling, and the results were plotted in the form of Langmuir isotherms. Experiments were conducted to determine the effect of grain size, coal type, moisture, and of sorbant gas. The advantage of this method is that it can be applied to very small samples, and it enabled comparison liptinite versus vitrinite concentrates, and kerogen rich versus kerogen depleted oil shales. Also included is a detailed discussion of the makeup of coal and its effect on gas sorption behavior.

Gas core reactors for coal gasification

International Nuclear Information System (INIS)

Weinstein, H.

1976-01-01

The concept of using a gas core reactor to produce hydrogen directly from coal and water is presented. It is shown that the chemical equilibrium of the process is strongly in favor of the production of H 2 and CO in the reactor cavity, indicating a 98 percent conversion of water and coal at only 1500 0 K. At lower temperatures in the moderator-reflector cooling channels the equilibrium strongly favors the conversion of CO and additional H 2 O to CO 2 and H 2 . Furthermore, it is shown the H 2 obtained per pound of carbon has 23 percent greater heating value than the carbon so that some nuclear energy is also fixed. Finally, a gas core reactor plant floating in the ocean is conceptualized which produces H 2 , fresh water and sea salts from coal

The external costs of electricity generation. A comparison of environmental damage of silicon photovoltaic electricity, produced with different electricity mixes, vs natural gas and coal

Energy Technology Data Exchange (ETDEWEB)

Olson, C.L.; Veltkamp, A.C.; Sinke, W.C. [ECN Solar Energy, Petten (Netherlands)

2012-09-15

In this paper the environmental damages of crystalline silicon photovoltaics are calculated, using the most recent photovoltaics data, and compared with those of the prevalent conventional energy technologies. A life cycle assessment of selected environmental impacts of 1kWh of electricity generated by various technologies was performed using Simapro software (version 7.2.4) in conjunction with the Ecoinvent database (version 2.2). The environmental impacts were assessed using the ReCiPe methodology. Because of the important role of coal and natural gas in the global electricity generation portfolio, special attention is given to the comparison of PV with those technologies. The environmental consequences of manufacturing PV modules with renewable, UCTE or 100% coal electricity mixes are explored. A brief update of the estimated monetarization of damages due to coal and climate change is included. A rough estimate of the true cost of coal and PV electricity is made in 2011.

Pilot plant experience in electron-beam treatment of iron-ore sintering flue gas and its application to coal boiler flue gas cleanup

International Nuclear Information System (INIS)

Kawamura, K.

1984-01-01

The present development status of the electron-beam flue gas treatment process, which is a dry process capable of removing SOx and NOx simultaneously, is described. The most advanced demonstration of this process was accomplished with a pilot plant in Japan where the maximum gas flow rate of 10,000 Nm 3 /h of an iron-ore sintering machine flue gas was successfully treated. The byproduct produced in this process is collected as a dry powder which is a mixture of ammonia sulfate and ammonium nitrate and is saleable as a fertilizer or a fertilizer component. A preliminary economic projection showed that this process costs less than the lime scrubber which removes SOx but does not remove NOx. Tests using simulated coal combustion gases suggest that this process will be applicable to coal-fired boiler flue gas treatment as well. However, tests on actual coal-fired flue gases are still required for commercial application decisions. A process development unit program consisting of the design, construction and testing of actual coal-fired power station flue gases is underway in the U.S.A. The design and engineering of the test plant is far advanced and the construction phase will be launched in the very near future. (author)

A Gas–Solid–Liquid Coupling Model of Coal Seams and the Optimization of Gas Drainage Boreholes

Directory of Open Access Journals (Sweden)

Yuexia Chen

2018-03-01

Full Text Available For a gas–solid–liquid coupling model of coal seams, previous permeability models basically supposed uniaxial strains as the boundary condition for coal reservoirs without considering the deformation caused by changes in humidity. The permeability model varies under different boundary conditions. According to the true triaxial stress state of coal reservoirs, a permeability model considering the effective stress, sorption and desorption, and wet strain was established. Based on the permeability model, the continuity equation of gas and water and the stress field equation were coupled. Then, the model was incorporated in the COMSOL suite to simulate gas drainage from boreholes in floor roadways passing through seams in a coal mine. By comparing with the measured gas flow on site, the model was verified as being reliable. Moreover, the spacing and layout shape of boreholes in floor roadways were simulated. To achieve the aim of eliminating regional outburst within 180 days and decreasing the number of boreholes so as to reduce the cost, the spacing and shape of boreholes were optimized. When the superimposed effect of the boreholes was not considered, the optimal spacing of boreholes was 3 r; if the superimposed effect was taken into account, the spacing could be set to within 3 r ≤ L ≤ R, where r and R represent the effective gas drainage radius and the influence radius of gas drainage, respectively. The borehole spacing could be appropriately increased when the boreholes were arranged in rhomboidal form. To achieve the same range of outburst elimination, the rhomboidal layout can decrease the number of boreholes to reduce cost, thus realizing the objective of this optimization process.

A study on measures to reduce production cost of long-running collieries and coal mining mechanization

Energy Technology Data Exchange (ETDEWEB)

NONE

1998-12-01

The reducing coal market has been enforcing the coal industry to make exceptional rationalization and restructuring efforts since the end of the eighties. To the competition from crude oil and natural gas has been added the growing pressure from rising wages and rising production cost as the working get deeper. To improve the competitive position of the remaining 11 coal mines after the rationalization of the industry, studies to improve mining system have been carried out. This report consists of 3 subjects. 1) Designing of the bord and pillar mining method to extract gently inclined seams of the Dogye coal mine. 2) Mechanization of coal cutting by plough. 3) Achievement of the mechanization of coal mining compared to the previous year. (author). 27 refs.

Damage cost of the Dan River coal ash spill

International Nuclear Information System (INIS)

Dennis Lemly, A.

2015-01-01

The recent coal ash spill on the Dan River in North Carolina, USA has caused several negative effects on the environment and the public. In this analysis, I report a monetized value for these effects after the first 6 months following the spill. The combined cost of ecological damage, recreational impacts, effects on human health and consumptive use, and esthetic value losses totals $295,485,000. Because the environmental impact and associated economic costs of riverine coal ash spills can be long-term, on the order of years or even decades, this 6-month assessment should be viewed as a short-term preview. The total cumulative damage cost from the Dan River coal ash spill could go much higher. - Highlights: • Six-month post-spill damage cost exceeded $295,000,000. • Components of cost include ecological, recreational, human health, property, and aesthetic values. • Attempts by the electric utility to “clean” the river left over 95% of coal ash behind. • Long-term impacts will likely drive the total damage cost much higher. - Damage costs of the Dan River coal ash spill are extensive and growing. The 6-month cost of that spill is valued at $295,485,000, and the long-term total cost is likely to rise substantially

Indication to distinguish the burst region of coal gas from seismic data

Energy Technology Data Exchange (ETDEWEB)

Jian-yuan Cheng; Hong-wei Tang; Lin Xu; Yan-fang Li [China Coal Research Institute, Xi' an (China). Xi' an Research Institute

2009-09-15

The velocity of an over-burst coal seam is about 1/3 compared to a normal coal seam based on laboratory test results. This can be considered as a basis to confirm the area of coal and gas burst by seismic exploration technique. Similarly, the simulation result of the theoretical seismic model shows that there is obvious distinction between over-burst coal and normal coal based on the coal reflection's travel-time, energy and frequency. The results from the actual seismic data acquired in the coal and gas over-burst cases is consistent with that of the laboratory and seismic modeling; that is, in the coal and gas burst region, seismic reflection travel time is delayed, seismic amplitude is weakened and seismic frequency is reduced. Therefore, it can be concluded that seismic exploration technique is promising for use in distinguishing coal and gas over-burst regions based on the variation of seismic reflection travel time, amplitude and frequency. 7 refs., 6 figs.

Survey of stranded gas and delivered costs to Europe of selected gas resources

Science.gov (United States)

Attanasi, E.D.; Freeman, P.A.

2011-01-01

Two important trends affecting the expected growth of global gas markets are (1) the shift by many industrialized countries from coal-fired electricity generation to the use of natural gas to generate electricity and (2) the industrialization of the heavily populated Asian countries of India and China. This paper surveys discovered gas in stranded conventional gas accumulations and presents estimates of the cost of developing and producing stranded gas in selected countries. Stranded gas is natural gas in discovered or identified fields that is not currently commercially producible for either physical or economic reasons. Published reserves of gas at the global level do not distinguish between volumes of gas in producing fields and volumes in nonproducing fields. Data on stranded gas reported here-that is the volumes, geographical distribution, and size distributions of stranded gas fields at the country and regional level-are based on the examination of individual-field data and represent a significant improvement in information available to industry and government decision makers. Globally, stranded gas is pervasive, but large volumes in large accumulations are concentrated in only a few areas. The cost component of the paper focuses on stranded conventional gas accumulations in Africa and South America that have the potential to augment supplies to Europe. The methods described for the computation of extraction and transport costs are innovative in that they use information on the sizes and geographical distribution of the identified stranded gas fields. The costs are based on industry data specific to the country and geologic basin where the stranded gas is located. Gas supplies to Europe can be increased significantly at competitive costs by the development of stranded gas. Net extraction costs of producing the identified gas depend critically on the natural-gas-liquids (NGLs) content, the prevailing prices of liquids, the size of the gas accumulation, and the

Numerical Assessment of the Influences of Gas Pressure on Coal Burst Liability

Directory of Open Access Journals (Sweden)

Haochen Zhao

2018-01-01

Full Text Available When coal mines exploit deep seams with high-gas content, risks are encountered due to the additional high likelihood of rock bursting potential problems. The bursts of coal pillars usually lead to severe fatalities, injuries, and destruction of property, including impeding access to active mine workings underground. The danger exists given that conditions in the already highly brittle coal material can be exacerbated by high stress and high gas pressure conditions. It is thus critical to develop methods that improve current understanding about bursting liability, and techniques to forecast or prevent coal bursting in underground coal mines. This study uses field data from a deep coal mine, and numerical modeling to investigate the effects of gas pressure and mechanical compressive stresses on coal bursting liability in high gas content coal seams. The bursting energy index is adopted to determine the coal bursting liability under high gas pressure conditions. The adopted methodology uses a two-staged approach comprising investigating the influence of gas pressure on the bursting liability of coal pillar, and the influence of the gas pressure on the resulting pillar failure mode. Based on numerical simulations of coal pillars, correlations are observed between the magnitudes of gas pressures and the bursting energy index. Irrespective of pillar size, failure time is shortest when the gas pressure achieves a threshold value between 50 kPa to 70 kPa. At 50 kPa, the value of the BEI increases by 50% going from the 4 m pillar to the 6 m pillar. The value of the BEI increases by 43% going from the 6 m high pillar to the 8 m high pillar at 50 kPa. When pillars fail there is a degree of stress relief leading to a reduction in bursting liability. The results suggest that before 50 kPa, pillar failure is largely due to mechanical loading. After 50 kPa, pillar failure is largely due to excessive gas pressures.

Techno-economic analysis of a coal-fired CHP based combined heating system with gas-fired boilers for peak load compensation

International Nuclear Information System (INIS)

Wang Haichao; Jiao Wenling; Lahdelma, Risto; Zou Pinghua

2011-01-01

Combined heat and power (CHP) plants dominate the heating market in China. With the ongoing energy structure reformation and increasing environmental concerns, we propose gas-fired boilers to be deployed in underperforming heating substations of heating networks for peak load compensation, in order to improve both energy efficiency and environmental sustainability. However, due to the relatively high price of gas, techno-economic analysis is required for evaluating different combined heating scenarios, characterized by basic heat load ratio (β). Therefore, we employ the dynamic economics and annual cost method to develop a techno-economic model for computing the net heating cost of the system, considering the current state of the art of cogeneration systems in China. The net heating cost is defined as the investment costs and operations costs of the system subtracted by revenues from power generation. We demonstrate the model in a real-life combined heating system of Daqing, China. The results show that the minimum net heating cost can be realized at β=0.75 with a cost reduction of 16.8% compared to coal heating alone. Since fuel cost is the dominating factor, sensitivity analyses on coal and gas prices are discussed subsequently. - Highlights: ► Combined heating systems comply with the energy structure reformation in China. ► We consider the current state of the art of cogeneration systems in China. ► Combined heating systems can be economically more feasible and sustainable. ► The net heating cost of a combined heating system is more sensitive to coal price. ► The optimal basic heat load ratio is more easily influenced by gas price.

Secured electrical supply at least cost: Coal, gas, nuclear, hydro

Energy Technology Data Exchange (ETDEWEB)

Gavor, J. [ENA Ltd., Prague (Czechoslovakia); Stary, O.; Vasicek, J. [Czech Technical Univ., Prague (Czechoslovakia)

1995-12-01

Electric power sector in East Central European countries finds in a difficult period. In the situation of demand stagnation, enormous investments must be realized in a very short time. Today`s decisions in the development strategy will influence the long term future of the industry. The optimal structure of the sources is one of the most important problem to be solved. Paper describes the current structure of the sources in electric power sector in the Czech Republic. The importance of coal, oil and gas, nuclear and hydro in electric power generation is compared. Taking into account the different position in the load coverage, economy of individual sources is evaluated and basic results of discounted cash flow calculations are presented. Information on specific investment programs and projects are included and further trends are estimated.

Biological conversion of coal gas to methane

Energy Technology Data Exchange (ETDEWEB)

Barik, S; Vega, J L; Clausen, E C; Gaddy, J L

1988-08-01

Biological conversion of low-Btu coal synthesis gas to higher Btu methane was demonstrated using both pure co-cultures and/or adapted-mixed anaerobic bacteria. Peptostreptococcus productus metabolized coal gas to mainly acetate and CO/sub 2/. The co-cultures containing methanogens converted these products to methane. In mixed culture studies, CH/sub 4/ and small amounts of acetate were produced. Reactor studies using stirred-tank and immobilized cell reactors exhibited excellent potential to convert CO, CO/sub 2/ and H/sub 2/ to methane at higher gas flow rates. Gas retention times ranging from 0.7 to 2 hours and high agitation were required for 90 percent CO conversion in these systems. This paper also illustrates the potential of biological methanation and demonstrates the need for good mass transfer in converting gas phase substrates. 21 refs., 1 fig., 7 tabs.

Oil, Gas, Coal and Electricity - Quarterly statistics. Second Quarter 2012

Energy Technology Data Exchange (ETDEWEB)

NONE

2012-07-15

This publication provides up-to-date and detailed quarterly statistics on oil, coal, natural gas and electricity for the OECD countries. Oil statistics cover production, trade, refinery intake and output, stock changes and consumption for crude oil, NGL and nine selected oil product groups. Statistics for electricity, natural gas, hard coal and brown coal show supply and trade. Import and export data are reported by origin and destination. Moreover, oil and hard coal production are reported on a worldwide basis.

Carbon charges and natural gas use in China

International Nuclear Information System (INIS)

Skeer, Jeffrey; Wang Yanjia

2006-01-01

Substitution of natural gas for coal in China's power sector could significantly reduce emissions of carbon dioxide, but gas-fired power is generally more costly than coal-fired power in China today. This paper explores how carbon charges and carbon sequestration technology might tip the balance in favour of gas. The costs of electricity from new coal-fired and gas-fired power plants in China are compared under various assumptions about fuel costs, exchange rates, carbon dioxide charges, and application of carbon sequestration technology. Under average cost conditions today, gas-fired power is roughly two-thirds more costly than coal-fired power. But with a charge of $20/tonne of carbon dioxide, the costs of gas- and coal-fired power would typically be about equal. Over the longer term, carbon sequestration technology could be economical with a carbon dioxide charge of $22/tonne or more under typical cost conditions, but gas with sequestration would not have a clear cost advantage over coal with sequestration unless the charge exceeded $35/tonne

Committing to coal and gas: Long-term contracts, regulation, and fuel switching in power generation

Science.gov (United States)

Rice, Michael

Fuel switching in the electricity sector has important economic and environmental consequences. In the United States, the increased supply of gas during the last decade has led to substantial switching in the short term. Fuel switching is constrained, however, by the existing infrastructure. The power generation infrastructure, in turn, represents commitments to specific sources of energy over the long term. This dissertation explores fuel contracts as the link between short-term price response and long-term plant investments. Contracting choices enable power plant investments that are relationship-specific, often regulated, and face uncertainty. Many power plants are subject to both hold-up in investment and cost-of-service regulation. I find that capital bias is robust when considering either irreversibility or hold-up due to the uncertain arrival of an outside option. For sunk capital, the rental rate is inappropriate for determining capital bias. Instead, capital bias depends on the regulated rate of return, discount rate, and depreciation schedule. If policies such as emissions regulations increase fuel-switching flexibility, this can lead to capital bias. Cost-of-service regulation can shorten the duration of a long-term contract. From the firm's perspective, the existing literature provides limited guidance when bargaining and writing contracts for fuel procurement. I develop a stochastic programming framework to optimize long-term contracting decisions under both endogenous and exogenous sources of hold-up risk. These typically include policy changes, price shocks, availability of fuel, and volatility in derived demand. For price risks, the optimal contract duration is the moment when the expected benefits of the contract are just outweighed by the expected opportunity costs of remaining in the contract. I prove that imposing early renegotiation costs decreases contract duration. Finally, I provide an empirical approach to show how coal contracts can limit

Advanced Acid Gas Separation Technology for the Utilization of Low Rank Coals

Energy Technology Data Exchange (ETDEWEB)

Kloosterman, Jeff

2012-12-31

Air Products has developed a potentially ground-breaking technology – Sour Pressure Swing Adsorption (PSA) – to replace the solvent-based acid gas removal (AGR) systems currently employed to separate sulfur containing species, along with CO{sub 2} and other impurities, from gasifier syngas streams. The Sour PSA technology is based on adsorption processes that utilize pressure swing or temperature swing regeneration methods. Sour PSA technology has already been shown with higher rank coals to provide a significant reduction in the cost of CO{sub 2} capture for power generation, which should translate to a reduction in cost of electricity (COE), compared to baseline CO{sub 2} capture plant design. The objective of this project is to test the performance and capability of the adsorbents in handling tar and other impurities using a gaseous mixture generated from the gasification of lower rank, lignite coal. The results of this testing are used to generate a high-level pilot process design, and to prepare a techno-economic assessment evaluating the applicability of the technology to plants utilizing these coals.

Two-stage coal liquefaction without gas-phase hydrogen

Science.gov (United States)

Stephens, H.P.

1986-06-05

A process is provided for the production of a hydrogen-donor solvent useful in the liquefaction of coal, wherein the water-gas shift reaction is used to produce hydrogen while simultaneously hydrogenating a donor solvent. A process for the liquefaction of coal using said solvent is also provided. The process enables avoiding the use of a separate water-gas shift reactor as well as high pressure equipment for liquefaction. 3 tabs.

Ceramic membranes for gas processing in coal gasification

Energy Technology Data Exchange (ETDEWEB)

Smart, S.; Lin, C.X.C.; Ding, L.; Thambimuthu, K.; da Costa, J.C.D. [University of Queensland, Brisbane, Qld. (Australia)

2010-07-01

Pre-combustion options via coal gasification, especially integrated gasification combined cycle (IGCC) processes, are attracting the attention of governments, industry and the research community as an attractive alternative to conventional power generation. It is possible to build an IGCC plant with CCS with conventional technologies however; these processes are energy intensive and likely to reduce power plant efficiencies. Novel ceramic membrane technologies, in particular molecular sieving silica (MSS) and pervoskite membranes, offer the opportunity to reduce efficiency losses by separating gases at high temperatures and pressures. MSS membranes can be made preferentially selective for H{sub 2}, enabling both enhanced production, via a water-gas shift membrane reactor, and recovery of H{sub 2} from the syngas stream at high temperatures. They also allow CO{sub 2} to be concentrated at high pressures, reducing the compression loads for transportation and enabling simple integration with CO{sub 2} storage or sequestration operations. Perovskite membranes provide a viable alternative to cryogenic distillation for air separation by delivering the tonnage of oxygen required for coal gasification at a reduced cost. In this review we examine ceramic membrane technologies for high temperature gas separation and discuss the operational, mechanical, design and process considerations necessary for their successful integration into IGCC with CCS systems.

18 CFR 270.302 - Occluded natural gas produced from coal seams.

Science.gov (United States)

2010-04-01

... produced from coal seams. 270.302 Section 270.302 Conservation of Power and Water Resources FEDERAL ENERGY... produced from coal seams. A person seeking a determination that natural gas is occluded natural gas produced from coal seams must file an application with the jurisdictional agency which contains the...

The future of coal as an energy source

International Nuclear Information System (INIS)

Rose, Ian

1998-01-01

The position of coal as the preferred fossil fuel for power generation is being challenged by gas. The total cost of production in $/kW/annum of coal generation compared with combined cycle gas turbine plant is illustrated for a range of annual capacity factors and fuel costs in the Australian context. lt is shown that plant capacity factors over 80%are required for coal-fired plants to be price competitive with gas. Unlike other fossil fuel energy types, the high capital cost of coal-fired plant means that new coal-fired plant will generally need to be base-loaded throughout their operating life to be competitive. However, experience shows that having installed the plant, it will operate as base-loaded, intermediate or peaking duty depending on market circumstances. Existing plants In New South Wales, Victoria and Queensland are generally operating at annual capacity factors that are below optimum levels. It is concluded that the coal-fired energy industry can be strongly challenged for the foreseeable future

Simulating greenhouse gas (GHG) allowance cost and GHG emission reduction in Western Europe

International Nuclear Information System (INIS)

Delarue, Erik; Lamberts, Hans; D'haeseleer, William

2007-01-01

Due to the growing concern for global warming, the EU25 have implemented the European Union Greenhouse Gas Emission Trading Scheme (EU ETS). In the first trading period (2005-2007), part of the targeted GHG emission reductions presumably will have to result from a switch from coal fired electricity generation to gas fired electricity generation. It is possible to calculate the allowance cost necessary to switch a certain coal fired plant with a certain gas fired plant in the merit order. The allowance cost obtained is a so called switching point. When comparing historic European Union Allowance (EUA) prices (2005) with the corresponding historic switching points, the EUA prices were found high enough to cause a certain switch in the summer season. This finding leads to the use of switching points in establishing allowance cost profiles for several scenarios. A variable gas price profile is used in the simulation tool E-Simulate to simulate electricity generation and related GHG emissions in an eight zonal model representing Western Europe. Several GHG allowance cost profile scenarios are examined. For each scenario, electricity generation in the considered countries is clarified. The focus however lies on the GHG emission reduction potentials. These potentials are addressed for each scenario

Determining the economic consequences of natural gas substitution

International Nuclear Information System (INIS)

Rimos, Shaun; Hoadley, Andrew F.A.; Brennan, David J.

2014-01-01

Highlights: • The economics of the extraction and usage of Australian gas and coal are examined. • Effect of feedstock substitution on power, hydrogen and ammonia costs is studied. • Influence of capital cost, transfer price, discount rate and carbon tax is studied. • Black coal has lower transfer price than gas but results in higher overall costs. • Conventional gas and coal seam gas can be substituted with little economic penalty. - Abstract: Resource depletion is a key aspect of sustainability, because the consumption of finite resources impacts on their availability for future generations. There are many proposed methods for accounting for the depletion of a particular resource, amongst which include the proportion of the resource depleted, the rate of resource depletion, and the energy, exergy, or monetary cost of extraction as the resource becomes harder to find or extract. This paper is part of a wider study to measure resource depletion using its environmental and economic impacts for the case of natural gas, where depletion of natural gas requires substitution by black coal or coal seam gas. The capital and operating costs are estimated both for upstream fuel extraction and purification and downstream use of the fuel to produce electricity, hydrogen and ammonia. These costs are based on a commercial scale of operation, using the same basis for economic modelling in each case. Black coal was found to have the lowest transfer price from upstream to downstream processing among the three feedstocks, but the highest capital and operating costs in the downstream processes. Conventional gas produced slightly higher transfer prices and downstream processing costs compared to coal seam gas. The favourable economic and environmental indicators for natural gas and coal seam gas are expected to lead to increased demand for these resources over coal, running the risk of a gas shortage. The economic consequence of a scarcity of either gas resource will be a

Acoustic Emission Characteristics of Gas-Containing Coal during Loading Dilation Process

Directory of Open Access Journals (Sweden)

Z. Q. Yin

2015-12-01

Full Text Available Raw coal was used as the study object in this paper to identify the evolution characteristics of acoustic emission (AE during the dilation process of gas-containing coal. The coal specimens were stored in gas seal devices filled with gas at different pressures (0, 0.5, 1.0, and 1.5 MPa for 24 h prior to testing. Then, the specimens were tested in a rock-testing machine, and the deformation and crack fracture patterns were recorded by using strain gauges and an AE system. The axial and volumetric strains–stress curves were analyzed in relation to the AE and the failure mode. Results show that as gas pressure increases, the uniaxial compression strength and elasticity modulus of gas-containing coal decreases, whereas the Poisson’s ratio increases. In all the coal specimens, the dilation initiation stress decreases, and the dilation degree increases. During the dilation process, before the loaded coal specimens reach peak stress, and as the load increases, the changes in the specimens and in the AE energy parameter of specimens can be divided into four phases: crack closure deformation, elastic deformation, stable crack propagation, and unstable crack propagation (dilation process. Across the four phases, the AE energy increases evidently during crack closure and elastic deformation but decreases during stable crack propagation. As the gas pressure increases, the AE signal frequency increases from 4.5 KHz to 8.1 KHz during the dilation process. Thus, the gas presence in coal specimens exerts a significant influence on the closure of sample cracks and dilation damage.

UNEP greenhouse gas abatement costing studies

International Nuclear Information System (INIS)

Maya, R.S.; Nziramasanga, N.; Muguti, E.; Fenhann, J.

1993-10-01

The aim was to assess options and cost of reducing emissions of greenhouse gases (with emphasis on carbon dioxide) from human activity in Zimbabwe. A brief description of the country's economy and energy sector, policy and pricing and regulations is given and substantial data related to the country's economy, technology, energy consumption, emission and fuel prices are presented. The energy demand in households and for other sectors in Zimbabwe are assessed, and documented in the case of the former. The reference scenarios on energy demand and supply assess greenhouse gas emissions under conditions whereby the present economic growth trends predominate. Energy efficiency improvements are discussed. Abatement technology options are stated as afforestation for carbon sequestration, more efficient coal-fired industrial boilers, extended use of hydroelectricity, prepayment electric meters, minimum tillage, optimization of coal-fired tobacco barns, industrial power factor correction equipment, domestic biogas digesters, solar water heating systems, time switches in electric geysers, optimization of industrial furnaces, photovoltaic water pumps, production of ammonia from coal for fertilizing purposes, and recovery of coke oven gases for use in thermal power generation. (AB)

An analysis of cost effective incentives for initial commercial deployment of advanced clean coal technologies

Energy Technology Data Exchange (ETDEWEB)

Spencer, D.F. [SIMTECHE, Half Moon Bay, CA (United States)

1997-12-31

This analysis evaluates the incentives necessary to introduce commercial scale Advanced Clean Coal Technologies, specifically Integrated Coal Gasification Combined Cycle (ICGCC) and Pressurized Fluidized Bed Combustion (PFBC) powerplants. The incentives required to support the initial introduction of these systems are based on competitive busbar electricity costs with natural gas fired combined cycle powerplants, in baseload service. A federal government price guarantee program for up to 10 Advanced Clean Coal Technology powerplants, 5 each ICGCC and PFBC systems is recommended in order to establish the commercial viability of these systems by 2010. By utilizing a decreasing incentives approach as the technologies mature (plants 1--5 of each type), and considering the additional federal government benefits of these plants versus natural gas fired combined cycle powerplants, federal government net financial exposure is minimized. Annual net incentive outlays of approximately 150 million annually over a 20 year period could be necessary. Based on increased demand for Advanced Clean Coal Technologies beyond 2010, the federal government would be revenue neutral within 10 years of the incentives program completion.

Study on Fluid-solid Coupling Mathematical Models and Numerical Simulation of Coal Containing Gas

Science.gov (United States)

Xu, Gang; Hao, Meng; Jin, Hongwei

2018-02-01

Based on coal seam gas migration theory under multi-physics field coupling effect, fluid-solid coupling model of coal seam gas was build using elastic mechanics, fluid mechanics in porous medium and effective stress principle. Gas seepage behavior under different original gas pressure was simulated. Results indicated that residual gas pressure, gas pressure gradient and gas low were bigger when original gas pressure was higher. Coal permeability distribution decreased exponentially when original gas pressure was lower than critical pressure. Coal permeability decreased rapidly first and then increased slowly when original pressure was higher than critical pressure.

Making concentrated solar power competitive with coal: The costs of a European feed-in tariff

International Nuclear Information System (INIS)

Williges, Keith; Lilliestam, Johan; Patt, Anthony

2010-01-01

The European Union has yet to determine how exactly to reach its greenhouse gas emissions targets for the future. One potential answer involves large-scale development of concentrated solar power (CSP) in the North African region, transmitting the power to Europe. CSP is a relatively young and little utilized technology and is expensive when compared to other methods of generation. Feasibility studies have shown it is possible to generate enough power from CSP plants in Africa to spearhead the EUs climate goals. However, the costs of such a project are less well known. Currently, CSP must compete with low cost coal-fired electricity plants, severely hindering development. We examine the possible investment costs required for North African CSP levelized electricity cost to equal those of coal-fired plants and the potential subsidy costs needed to encourage growth until the technologies reach price parity. We also examine the sensitivity of investment and subsidies to changes in key factors. We find that estimates of subsidy amounts are reasonable for the EU and that sensitivity to such factors as perceived risk and learning rates would enable policy-makers to positively influence the cost of subsidies and time required for CSP to be competitive with coal.

Propagation characteristics of pulverized coal and gas two-phase flow during an outburst.

Science.gov (United States)

Zhou, Aitao; Wang, Kai; Fan, Lingpeng; Tao, Bo

2017-01-01

Coal and gas outbursts are dynamic failures that can involve the ejection of thousands tons of pulverized coal, as well as considerable volumes of gas, into a limited working space within a short period. The two-phase flow of gas and pulverized coal that occurs during an outburst can lead to fatalities and destroy underground equipment. This article examines the interaction mechanism between pulverized coal and gas flow. Based on the role of gas expansion energy in the development stage of outbursts, a numerical simulation method is proposed for investigating the propagation characteristics of the two-phase flow. This simulation method was verified by a shock tube experiment involving pulverized coal and gas flow. The experimental and simulated results both demonstrate that the instantaneous ejection of pulverized coal and gas flow can form outburst shock waves. These are attenuated along the propagation direction, and the volume fraction of pulverized coal in the two-phase flow has significant influence on attenuation of the outburst shock wave. As a whole, pulverized coal flow has a negative impact on gas flow, which makes a great loss of large amounts of initial energy, blocking the propagation of gas flow. According to comparison of numerical results for different roadway types, the attenuation effect of T-type roadways is best. In the propagation of shock wave, reflection and diffraction of shock wave interact through the complex roadway types.

Power generation costs. Coal - nuclear power

International Nuclear Information System (INIS)

1979-01-01

This supplement volume contains 17 separate chapters investigating the parameters which determine power generation costs on the basis of coal and nuclear power and a comparison of these. A detailed calculation model is given. The complex nature of this type of cost comparison is shown by a review of selected parameter constellation for coal-fired and nuclear power plants. The most favourable method of power generation can only be determined if all parameters are viewed together. One quite important parameter is the load factor, or rather the hours of operation. (UA) 891 UA/UA 892 AMO [de

Coal-packed methane biofilter for mitigation of green house gas emissions from coal mine ventilation air.

Science.gov (United States)

Limbri, Hendy; Gunawan, Cindy; Thomas, Torsten; Smith, Andrew; Scott, Jason; Rosche, Bettina

2014-01-01

Methane emitted by coal mine ventilation air (MVA) is a significant greenhouse gas. A mitigation strategy is the oxidation of methane to carbon dioxide, which is approximately twenty-one times less effective at global warming than methane on a mass-basis. The low non-combustible methane concentrations at high MVA flow rates call for a catalytic strategy of oxidation. A laboratory-scale coal-packed biofilter was designed and partially removed methane from humidified air at flow rates between 0.2 and 2.4 L min-1 at 30°C with nutrient solution added every three days. Methane oxidation was catalysed by a complex community of naturally-occurring microorganisms, with the most abundant member being identified by 16S rRNA gene sequence as belonging to the methanotrophic genus Methylocystis. Additional inoculation with a laboratory-grown culture of Methylosinus sporium, as investigated in a parallel run, only enhanced methane consumption during the initial 12 weeks. The greatest level of methane removal of 27.2±0.66 g methane m-3 empty bed h-1 was attained for the non-inoculated system, which was equivalent to removing 19.7±2.9% methane from an inlet concentration of 1% v/v at an inlet gas flow rate of 1.6 L min-1 (2.4 min empty bed residence time). These results show that low-cost coal packing holds promising potential as a suitable growth surface and contains methanotrophic microorganisms for the catalytic oxidative removal of methane.

Energy supply: No gas from coal

Energy Technology Data Exchange (ETDEWEB)

Kempkens, W

1983-03-01

In the last twelve years the share of natural gas in the total consumption of primary energy has increased twelve-fold and now amounts to 16 per cent. One-third of this is produced in West Germany. Although world deposits will last well into the next century, attempts are already being made to perfect techniques for obtaining gas from coal. However, the cubic metre price of synthetic gas is still anything but competitive.

Power-generating process of obtaining gas-energy carrier and reducer from coal

International Nuclear Information System (INIS)

Tleugabulov, S.; Duncheva, E.; Zubkevich, M.

1999-01-01

The manufacture of power-generating gas has the important economic value for Kazakhstan having large territory, raw and fuel resources especially power coal and clean coal wastes. The technology of reception of gas-energy carrier and reducer from power coal is developed. The basic product of technological process is heated reducing gas. Reducing potential of the gas is characterized by a volumetric share of components (CO+H 2 )-RC in relation to volume of whole mix of gases received with gasification of coal. The value of parameter RC is regulated by a degree of enrichment of air by oxygen r 0 , and the temperature - by the charge of a parity of endothermic reaction in the chamber of gas regeneration. The dependence of the gas structure and temperature on the degree of enrichment of air by oxygen is shown and the circuit of the gas generator is given. (author)

Latest condition of the steam coal market and outlook for supply cost

Energy Technology Data Exchange (ETDEWEB)

Murase, A.

1988-11-01

The following factors affecting coal prices are identified: rises in the prices of fuels which compete with coal, especially petroleum; the supply cost of coal; coal supply and demand; the balance of power between sellers and buyers; and foreign exchange rates. Coal supply costs are discussed. 5 figs.

Sustainable application of reciprocating gas engines operating on coal mine methane

Energy Technology Data Exchange (ETDEWEB)

Lee, J.; Teo, T. [Caterpillar China Investment Co., Beijing (China); Tnay, C.H. [Westrac Inc., Beijing (China)

2008-07-01

According to the World Coal Institute, coal provides 25 per cent of worldwide primary energy needs and generates 40 per cent of the world's electricity. China produces the largest amount of hard coal. The anthropogenic release of methane (CH{sub 4}) into the environment is a byproduct of the coal mining process. The global warming potential of this methane continues to draw attention around the world. In particular, China's government has recognized the need for environmental responsibility in the pursuit of greater power production. The Kyoto Protocol requires developed countries to reduce their greenhouse gas emissions and targets must be met within a five-year time frame between 2008 and 2012. Sequestering coal mine methane (CMM) as an alternative fuel for reciprocating gas engine generator sets is a mature and proven technology for greenhouse gas mitigation. Prior to commissioning CMM-fueled power systems, the methane gas composition must be evaluated. An integrated systems approach can then be used to develop a CMM-fueled power project. This paper discussed the sustainable application of reciprocating gas engines operating on coal mine methane. It discussed the Kyoto Protocol, clean development mechanism, and CMM as compared to other fuel sources. It was concluded that there is considerable opportunity for growth in the Asia-Pacific region for electric power applications using CMM. 4 refs., 12 figs.

The effect of a tectonic stress field on coal and gas outbursts.

Science.gov (United States)

An, Fenghua; Cheng, Yuanping

2014-01-01

Coal and gas outbursts have always been a serious threat to the safe and efficient mining of coal resources. Ground stress (especially the tectonic stress) has a notable effect on the occurrence and distribution of outbursts in the field practice. A numerical model considering the effect of coal gas was established to analyze the outburst danger from the perspective of stress conditions. To evaluate the outburst tendency, the potential energy of yielded coal mass accumulated during an outburst initiation was studied. The results showed that the gas pressure and the strength reduction from the adsorbed gas aggravated the coal mass failure and the ground stress altered by tectonics would affect the plastic zone distribution. To demonstrate the outburst tendency, the ratio of potential energy for the outburst initiation and the energy consumption was used. Increase of coal gas and tectonic stress could enhance the potential energy accumulation ratio, meaning larger outburst tendency. The component of potential energy for outburst initiation indicated that the proportion of elastic energy was increased due to tectonic stress. The elastic energy increase is deduced as the cause for a greater outburst danger in a tectonic area from the perspective of stress conditions.

Integrated Warm Gas Multicontaminant Cleanup Technologies for Coal-Derived Syngas

Energy Technology Data Exchange (ETDEWEB)

Turk, Brian; Gupta, Raghubir; Sharma, Pradeepkumar; Albritton, Johnny; Jamal, Aqil

2010-09-30

One of the key obstacles for the introduction of commercial gasification technology for the production of power with Integrated Gasification Combined Cycle (IGCC) plants or the production of value added chemicals, transportation fuels, and hydrogen has been the cost of these systems. This situation is particularly challenging because the United States has ample coal resources available as raw materials and effective use of these raw materials could help us meet our energy and transportation fuel needs while significantly reducing our need to import oil. One component of the cost of these systems that faces strong challenges for continuous improvement is removing the undesirable components present in the syngas. The need to limit the increase in cost of electricity to < 35% for new coal-based power plants which include CO{sub 2} capture and sequestration addresses both the growing social concern for global climate change resulting from the emission of greenhouse gas and in particular CO{sub 2} and the need to control cost increases to power production necessary to meet this social objective. Similar improvements to technologies for trace contaminants are getting similar pressure to reduce environmental emissions and reduce production costs for the syngas to enable production of chemicals from coal that is cost competitive with oil and natural gas. RTI, with DOE/NETL support, has been developing sorbent technologies that enable capture of trace contaminants and CO{sub 2} at temperatures above 400 °F that achieve better capture performance, lower costs and higher thermal efficiency. This report describes the specific work of sorbent development for mercury (Hg), arsenic (As), selenium (Se), cadmium (Cd), and phosphorous (P) and CO{sub 2} removal. Because the typical concentrations of Hg, As, Se, Cd, and P are less than 10 ppmv, the focus has been on single-use sorbents with sufficient capacity to ensure replacement costs are cost effective. The research in this

Impact of Contaminants Present in Coal-Biomass Derived Synthesis Gas on Water-gas Shift and Fischer-Tropsch Synthesis Catalysts

Energy Technology Data Exchange (ETDEWEB)

Alptekin, Gokhan [TDA Research, Inc., Wheat Ridge, CO (United States)

2013-02-15

Co-gasification of biomass and coal in large-scale, Integrated Gasification Combined Cycle (IGCC) plants increases the efficiency and reduces the environmental impact of making synthesis gas ("syngas") that can be used in Coal-Biomass-to-Liquids (CBTL) processes for producing transportation fuels. However, the water-gas shift (WGS) and Fischer-Tropsch synthesis (FTS) catalysts used in these processes may be poisoned by multiple contaminants found in coal-biomass derived syngas; sulfur species, trace toxic metals, halides, nitrogen species, the vapors of alkali metals and their salts (e.g., KCl and NaCl), ammonia, and phosphorous. Thus, it is essential to develop a fundamental understanding of poisoning/inhibition mechanisms before investing in the development of any costly mitigation technologies. We therefore investigated the impact of potential contaminants (H₂S, NH₃, HCN, AsH₃, PH₃, HCl, NaCl, KCl, AS₃, NH₄NO₃, NH₄OH, KNO₃, HBr, HF, and HNO₃) on the performance and lifetime of commercially available and generic (prepared in-house) WGS and FT catalysts.

Greenhouse gas emissions from shale gas and coal for electricity generation in South Africa

Directory of Open Access Journals (Sweden)

Brett Cohen

2014-03-01

Full Text Available There is increased interest, both in South Africa and globally, in the use of shale gas for electricity and energy supply. The exploitation of shale gas is, however, not without controversy, because of the reported environmental impacts associated with its extraction. The focus of this article is on the greenhouse gas footprint of shale gas, which some literature suggests may be higher than what would have been expected as a consequence of the contribution of fugitive emissions during extraction, processing and transport. Based on some studies, it has been suggested that life-cycle emissions may be higher than those from coal-fired power. Here we review a number of studies and analyse the data to provide a view of the likely greenhouse gas emissions from producing electricity from shale gas, and compare these emissions to those of coal-fired power in South Africa. Consideration was given to critical assumptions that determine the relative performance of the two sources of feedstock for generating electricity � that is the global warming potential of methane and the extent of fugitive emissions. The present analysis suggests that a 100-year time horizon is appropriate in analysis related to climate change, over which period the relative contribution is lower than for shorter periods. The purpose is to limit temperature increase in the long term and the choice of metric should be appropriate. The analysis indicates that, regardless of the assumptions about fugitive emissions and the period over which global warming potential is assessed, shale gas has lower greenhouse gas emissions per MWh of electricity generated than coal. Depending on various factors, electricity from shale gas would have a specific emissions intensity between 0.3 tCO2/MWh and 0.6 tCO2/MWh, compared with about 1 tCO2/MWh for coal-fired electricity in South Africa.

Reservoir characteristics of coal-shale sedimentary sequence in coal-bearing strata and their implications for the accumulation of unconventional gas

Science.gov (United States)

Wang, Yang; Zhu, Yanming; Liu, Yu; Chen, Shangbin

2018-04-01

Shale gas and coalbed methane (CBM) are both considered unconventional natural gas and are becoming increasingly important energy resources. In coal-bearing strata, coal and shale are vertically adjacent as coal and shale are continuously deposited. Research on the reservoir characteristics of coal-shale sedimentary sequences is important for CBM and coal-bearing shale gas exploration. In this study, a total of 71 samples were collected, including coal samples (total organic carbon (TOC) content >40%), carbonaceous shale samples (TOC content: 6%-10%), and shale samples (TOC content TOC content. Clay and quartz also have a great effect on the porosity of shale samples. According to the FE-SEM image technique, nanoscale pores in the organic matter of coal samples are much more developed compared with shale samples. For shales with low TOC, inorganic minerals provide more pores than organic matter. In addition, TOC content has a positive relationship with methane adsorption capacity, and the adsorption capacity of coal samples is more sensitive than the shale samples to temperature.

Coal-Packed Methane Biofilter for Mitigation of Green House Gas Emissions from Coal Mine Ventilation Air

Science.gov (United States)

Limbri, Hendy; Gunawan, Cindy; Thomas, Torsten; Smith, Andrew; Scott, Jason; Rosche, Bettina

2014-01-01

Methane emitted by coal mine ventilation air (MVA) is a significant greenhouse gas. A mitigation strategy is the oxidation of methane to carbon dioxide, which is approximately twenty-one times less effective at global warming than methane on a mass-basis. The low non-combustible methane concentrations at high MVA flow rates call for a catalytic strategy of oxidation. A laboratory-scale coal-packed biofilter was designed and partially removed methane from humidified air at flow rates between 0.2 and 2.4 L min−1 at 30°C with nutrient solution added every three days. Methane oxidation was catalysed by a complex community of naturally-occurring microorganisms, with the most abundant member being identified by 16S rRNA gene sequence as belonging to the methanotrophic genus Methylocystis. Additional inoculation with a laboratory-grown culture of Methylosinus sporium, as investigated in a parallel run, only enhanced methane consumption during the initial 12 weeks. The greatest level of methane removal of 27.2±0.66 g methane m−3 empty bed h−1 was attained for the non-inoculated system, which was equivalent to removing 19.7±2.9% methane from an inlet concentration of 1% v/v at an inlet gas flow rate of 1.6 L min−1 (2.4 min empty bed residence time). These results show that low-cost coal packing holds promising potential as a suitable growth surface and contains methanotrophic microorganisms for the catalytic oxidative removal of methane. PMID:24743729

Combustion of coal gas fuels in a staged combustor

Science.gov (United States)

Rosfjord, T. J.; Mcvey, J. B.; Sederquist, R. A.; Schultz, D. F.

1982-01-01

Gaseous fuels produced from coal resources generally have heating values much lower than natural gas; the low heating value could result in unstable or inefficient combustion. Coal gas fuels may contain ammonia which if oxidized in an uncontrolled manner could result in unacceptable nitrogen oxide exhaust emission levels. Previous investigations indicate that staged, rich-lean combustion represents a desirable approach to achieve stable, efficient, low nitrogen oxide emission operation for coal-derived liquid fuels contaning up to 0.8-wt pct nitrogen. An experimental program was conducted to determine whether this fuel tolerance can be extended to include coal-derived gaseous fuels. The results of tests with three nitrogen-free fuels having heating values of 100, 250, and 350 Btu/scf and a 250 Btu/scf heating value doped to contain 0.7 pct ammonia are presented.

Peabody Western Coal cuts costs with bottom-dump haulers

Energy Technology Data Exchange (ETDEWEB)

Perla, S.; Baecker, G.; Morgan, W. [Empire Machinery, Mesa, AZ (United States)

1995-04-01

A new hauling concept has been introduced at the Black Mesa and Kayenta coal mines of the Peabody Western Coal Co. in northern Arizona, USA. The article describes the switch from Caterpillar 992 wheel loaders with 136 t bottom-dump trucks to 272 t bottom-dump trucks. Cat 789 off-highway trucks were modified to pull bottom-dump trucks. Haulage costs per ton of coal and cost per ton-mile have fallen significantly since the introduction of the new large hauling method. 7 figs., 2 photos.

Analysis of gas migration patterns in fractured coal rocks under actual mining conditions

Directory of Open Access Journals (Sweden)

Gao Mingzhong

2017-01-01

Full Text Available Fracture fields in coal rocks are the main channels for gas seepage, migration, and extraction. The development, evolution, and spatial distribution of fractures in coal rocks directly affect the permeability of the coal rock as well as gas migration and flow. In this work, the Ji-15-14120 mining face at the No. 8 Coal Mine of Pingdingshan Tian’an Coal Mining Co. Ltd., Pingdingshan, China, was selected as the test site to develop a full-parameter fracture observation instrument and a dynamic fracture observation technique. The acquired video information of fractures in the walls of the boreholes was vectorized and converted to planarly expanded images on a computer-aided design platform. Based on the relative spatial distances between the openings of the boreholes, simultaneous planar images of isolated fractures in the walls of the boreholes along the mining direction were obtained from the boreholes located at various distances from the mining face. Using this information, a 3-D fracture network under mining conditions was established. The gas migration pattern was calculated using a COMSOL computation platform. The results showed that between 10 hours and 1 day the fracture network controlled the gas-flow, rather than the coal seam itself. After one day, the migration of gas was completely controlled by the fractures. The presence of fractures in the overlying rock enables the gas in coal seam to migrate more easily to the surrounding rocks or extraction tunnels situated relatively far away from the coal rock. These conclusions provide an important theoretical basis for gas extraction.

Gas and coal competition in the EU power sector

International Nuclear Information System (INIS)

Cornot-Gandolphe, Sylvie

2014-01-01

According to a new report by CEDIGAZ, the International Centre for Natural Gas Information, gas has lost its attractiveness against coal in the EU power sector. Its demand by the sector decreased by one third during the past three years and its prospects are very weak in this decade. The Association warns that un-profitability of combined cycle gas turbines (CCGTs) and the retirement of old coal plants due to stringent air regulation may lead to the closure of one third of the current fleet and poses a serious security of supply issue that has to be addressed urgently

CO{sub 2} emission costs and Gas/Coal competition for power production; Prezzi delle emissioni di CO{sub 2} e competivita' gas/carbone per la produzione termoelettrica

Energy Technology Data Exchange (ETDEWEB)

Santi, Federico [La Sapienza Univ., Roma (Italy). Dipartimento di Ingegneria Nucleare e Conversioni dell' Energia

2005-05-01

This paper demonstrates how a CO{sub 2} emission reduction programme can change the competition between the two power production technologies which will probably dominate the future of the Italian power industry: the coal fired USC steam power plant and the natural gas fired CCGT power plant. An economic value of the CO{sub 2} emission is calculated, in order to make the short-run-marginal-cost (or the long-run-marginal-cost). equal for both technologies, under a CO{sub 2} emission trading scheme and following a single-plant specific CO{sub 2} emission homogenizing approach. [Italian] Si dimostra come un programma teso alla riduzione delle emissioni di CO{sub 2} possa mutare la competivita' tra le due tecnologie per la produzione termoelettrica che saranno dominanti nel prossimo futuro in Italia: le centrali a carbone USC e le centrali CCGT a gas naturale. Si calcola il prezzo delle emissioni di CO{sub 2} per valutare il costo marginale di breve periodo (o il costo marginale di lungo periodo) per entrambe le tecnologie, avvalendosi di un programma di emission trading e utilizzando un approccio di omogeneizzazione delle emissioni di CO{sub 2} specifiche di ogni impianto.

Gas Concentration Prediction Based on the Measured Data of a Coal Mine Rescue Robot

Directory of Open Access Journals (Sweden)

Xiliang Ma

2016-01-01

Full Text Available The coal mine environment is complex and dangerous after gas accident; then a timely and effective rescue and relief work is necessary. Hence prediction of gas concentration in front of coal mine rescue robot is an important significance to ensure that the coal mine rescue robot carries out the exploration and search and rescue mission. In this paper, a gray neural network is proposed to predict the gas concentration 10 meters in front of the coal mine rescue robot based on the gas concentration, temperature, and wind speed of the current position and 1 meter in front. Subsequently the quantum genetic algorithm optimization gray neural network parameters of the gas concentration prediction method are proposed to get more accurate prediction of the gas concentration in the roadway. Experimental results show that a gray neural network optimized by the quantum genetic algorithm is more accurate for predicting the gas concentration. The overall prediction error is 9.12%, and the largest forecasting error is 11.36%; compared with gray neural network, the gas concentration prediction error increases by 55.23%. This means that the proposed method can better allow the coal mine rescue robot to accurately predict the gas concentration in the coal mine roadway.

Greenhouse gas emission factor development for coal-fired power plants in Korea

International Nuclear Information System (INIS)

Jeon, Eui-Chan; Myeong, Soojeong; Sa, Jae-Whan; Kim, Jinsu; Jeong, Jae-Hak

2010-01-01

Accurate estimation of greenhouse gas emissions is essential for developing an appropriate strategy to mitigate global warming. This study examined the characteristics of greenhouse gas emission from power plants, a major greenhouse gas source in Korea. The power plants examined use bituminous coal, anthracite, and sub-bituminous coal as fuel. The CO 2 concentration from power plants was measured using GC-FID with methanizer. The amount of carbon, hydrogen, and calorific values in the input fuel was measured using an elemental analyzer and calorimeter. For fuel analysis, CO 2 emission factors for anthracite, bituminous coal, and sub-bituminous coal were 108.9, 88.4, and 97.9 Mg/kJ, respectively. The emission factors developed in this study were compared with those for IPCC. The results showed that CO 2 emission was 10.8% higher for anthracite, 5.5% lower for bituminous coal, and 1.9% higher for sub-bituminous coal than the IPCC figures.

The economic production of alcohol fuels from coal-derived synthesis gas

Energy Technology Data Exchange (ETDEWEB)

Kugler, E.L.; Dadyburjor, D.B.; Yang, R.Y.K. [West Virginia Univ., Morgantown, WV (United States)] [and others

1995-12-31

The objectives of this project are to discover, (1) study and evaluate novel heterogeneous catalytic systems for the production of oxygenated fuel enhancers from synthesis gas. Specifically, alternative methods of preparing catalysts are to be investigated, and novel catalysts, including sulfur-tolerant ones, are to be pursued. (Task 1); (2) explore, analytically and on the bench scale, novel reactor and process concepts for use in converting syngas to liquid fuel products. (Task 1); (3) simulate by computer the most energy efficient and economically efficient process for converting coal to energy, with primary focus on converting syngas to fuel alcohols. (Task 2); (4) develop on the bench scale the best holistic combination of chemistry, catalyst, reactor and total process configuration integrated with the overall coal conversion process to achieve economic optimization for the conversion of syngas to liquid products within the framework of achieving the maximum cost effective transformation of coal to energy equivalents. (Tasks 1 and 2); and (5) evaluate the combustion, emission and performance characteristics of fuel alcohols and blends of alcohols with petroleum-based fuels. (Task 2)

Emission of CO2 Gas and Radioactive Pollutant from Coal Fired Power Plant

International Nuclear Information System (INIS)

Ida, N.Finahari; Djati-HS; Heni-Susiati

2006-01-01

Energy utilization for power plant in Indonesia is still depending on burning fossil fuel such as coal, oil and gaseous fuel. The direct burning of coal produces CO 2 gas that can cause air pollution, and radioactive pollutant that can increase natural radioactive dosage. Natural radionuclide contained in coal is in the form of kalium, uranium, thorium and their decay products. The amount of CO 2 gas emission produced by coal fired power plant can be reduced by equipping the plant with waste-gas treatment facility. At this facility, CO 2 gas is reacted with calcium hydroxide producing calcium carbonate. Calcium carbonate then can be used as basic material in food, pharmaceutical and construction industries. The alternative method to reduce impact of air pollution is by replacing coal fuel with nuclear fuel or new and renewable fuel. (author)

Update on the REIPPPP, clean coal, nuclear, natural gas

CSIR Research Space (South Africa)

Milazi, Dominic

2015-12-01

Full Text Available , clean coal, nuclear, natural gas The Sustainable Energy Resource Handbook Volume 6 Dominic Milazi, Dr Tobias Bischof-Niemz, Abstract Since its release in 2011, the Integrated Resource Plan (IRP 2010-2030), or IRP 2010, has been the authoritative... text setting out South Africa’s electricity plan over the next 20 years. The document indicates timelines on the roll out of key supply side options such as renewable energy, the nuclear, natural gas and coal build programmes, as well as peaking...

Visual detection of gas shows from coal core and cuttings using liquid leak detector

Energy Technology Data Exchange (ETDEWEB)

Barker, C.E. [United States Geological Survey, Denver, CO (United States)

2006-09-15

Coal core descriptions are difficult to obtain, as they must be obtained immediately after the core is retrieved and before the core is closed in a canister. This paper described a method of marking gas shows on a core surface by coating the core with a water-based liquid leak detector and photographing the subsequent foam developed on the core surface while the core is still in the core tray. Coals from a borehole at the Yukon Flats Basin in Alaska and the Maverick Basin in Texas were used to illustrate the method. Drilling mud and debris were removed from the coal samples before the leak detector solution was applied onto the core surfaces. A white froth or dripping foam developed rapidly at gas shows on the sample surfaces. A hand-held lens and a binocular microscope were used to magnify the foaming action. It was noted that foaming was not continuous across the core surface, but was restricted to localized points along the surface. It was suggested that the localized point foaming may have resulted from the coring process. However, the same tendency toward point gas show across the sample surface was found in some hard, well-indurated samples that still had undisturbed bedding and other sedimentary structures. It was concluded that gas shows marked as separate foam centres may indicate a real condition of local permeability paths. Results suggested that the new gas show detection method could be used in core selection studies to reduce the costs of exploration programs. 6 refs., 4 figs.

Reducing the greenhouse gas footprint of shale gas

International Nuclear Information System (INIS)

Wang Jinsheng; Ryan, David; Anthony, Edward J.

2011-01-01

Shale gas is viewed by many as a global energy game-changer. However, serious concerns exist that shale gas generates more greenhouse gas emissions than does coal. In this work the related published data are reviewed and a reassessment is made. It is shown that the greenhouse gas effect of shale gas is less than that of coal over long term if the higher power generation efficiency of shale gas is taken into account. In short term, the greenhouse gas effect of shale gas can be lowered to the level of that of coal if methane emissions are kept low using existing technologies. Further reducing the greenhouse gas effect of shale gas by storing CO 2 in depleted shale gas reservoirs is also discussed, with the conclusion that more CO 2 than the equivalent CO 2 emitted by the extracted shale gas could be stored in the reservoirs at significantly reduced cost. - Highlights: ► The long-term greenhouse gas footprint of shale gas is smaller than that of coal. ► Carbon capture and storage should be considered for fossil fuels including shale gas. ► Depleted shale gas fields could store more CO 2 than the equivalent emissions. ► Linking shale gas development with CO 2 storage could largely reduce the total cost.

Sorption characteristic of coal as regards of gas mixtures emitted in the process of the self-heating of coal

Directory of Open Access Journals (Sweden)

Wojtacha-Rychter Karolina

2017-01-01

Full Text Available One of the most challenging tasks in the coal mining sector is the detection of endogenous fire risks. Under field conditions, the distance between the points where samples for the analyses are collected and the actual place where coal self-heating takes place may be quite remote. Coal is a natural sorbent with a diverse character of pore structures which are surrounded by fractures and cleavage planes constituting ideal spaces for the flow and adsorption of gases. The gases (methane, ethane, ethylene, propane, propylene, acetylene, carbon dioxide, carbon monoxide, hydrogen released from the source of fire migrate through the seam and may be subject to adsorption, or they may cause the desorption of gases accumulated in coal. Therefore, the values of reference sample concentrations may be overstated or understated, respectively. The objective of this experimental study was to investigate the adsorption phenomena accompanying the flow of a multi-component gas mixture through a coal bed which may occur in situ. The research was conducted by means of a method based on a series of calorimetric/chromatographic measurements taken to determine the amount of gases released during coal heating at various temperatures under laboratory conditions. Based on the results obtained in the course of the experiments, it was concluded that the amount of gas adsorbed in the seam depends on the type of coal and the gas. Within the multi-component gas mixture, hydrocarbons demonstrated the largest sorption capacity, especially as concerns propylene.

Stress and Damage Induced Gas Flow Pattern and Permeability Variation of Coal from Songzao Coalfield in Southwest China

Directory of Open Access Journals (Sweden)

Minghui Li

2016-05-01

Full Text Available The permeability of coal is a critical parameter in estimating the performance of coal reservoirs. Darcy’s law describes the flow pattern that the permeability has a linear relationship with the flow velocity. However, the stress induced deformation and damage can significantly influence the gas flow pattern and permeability of coal. Coals from Songzao coalfield in Chongqing, southwest China were collected for the study. The gas flow velocities under different injection gas pressures and effective stresses in the intact coal and damaged coal were tested using helium, incorporating the role of gas flow pattern on the permeability of coal. The relationships between the flow velocity and square of gas pressure gradient were discussed, which can help us to investigate the transformation conditions of gas linear flow and gas nonlinear flow in the coal. The results showed that the gas flow in the intact coal existed pseudo-initial flow rate under low effective stress. The low-velocity non-Darcy gas flow gradually occurred and the start-up pressure gradient increased in the coal as the effective stress increased. The gas flow rate in the damaged coal increased nonlinearly as the square of pressure gradient increased under low effective stress. The instability of gas flow caused by high ratio of injection gas pressure over effective stress in the damaged coal contributed to the increase of the gas flow rate. As the effective stress increased, the increase of gas flow rate in coal turned to be linear. The mechanisms of the phenomena were explored according to the experimental results. The permeability of coal was corrected based on the relationships between the flow velocity and square of gas pressure gradient, which showed advantages in accurately estimating the performance of coal reservoirs.

Gas Hydrates of Coal Layers as a Methane Source in the Atmosphere and Mine Working

Science.gov (United States)

Dyrdin, Valery; Shepeleva, Sofya; Kim, Tatiana

2017-11-01

Living conditions of gas hydrates of a methane in a coal matrix as one of possible forms of finding of molecules of a methane in coal layers are considered. However, gas hydrates are formed not in all mineral coals even under the thermobaric conditions corresponding to their equilibrium state as the minimum humidity and the corresponding pore width are necessary for each brand of coal for formation of gas hydrate. It is shown that it depends on electric electrical dipole moment of a macromolecule of coal. Coals of brands K, D, Zh were considered. The electric field created by the surface of coal does not allow molecules of water to carry out threedimensional driving, and they keep on an internal surface of a time. By means of theoretical model operation a dipole - dipole interaction of molecules of water with the steam surface of coal values of energy of fiber interaction for various functional groups located in coal "fringe" which size for the first and second layers does not allow molecules of water to participate in formation of gas hydrates are received. For coals of brands K, Zh, D, considering distribution of a time on radiuses, the percent of moisture, which cannot share in education solid coal of gas solutions, is calculated.

A New Tree-Type Fracturing Method for Stimulating Coal Seam Gas Reservoirs

Directory of Open Access Journals (Sweden)

Qian Li

2017-09-01

Full Text Available Hydraulic fracturing is used widely to stimulate coalbed methane production in coal mines. However, some factors associated with conventional hydraulic fracturing, such as the simple morphology of the fractures it generates and inhomogeneous stress relief, limit its scope of application in coal mines. These problems mean that gas extraction efficiency is low. Conventional fracturing may leave hidden pockets of gas, which will be safety hazards for subsequent coal mining operations. Based on a new drilling technique applicable to drilling boreholes in coal seams, this paper proposes a tree-type fracturing technique for stimulating reservoir volumes. Tree-type fracturing simulation experiments using a large-scale triaxial testing apparatus were conducted in the laboratory. In contrast to the single hole drilled for conventional hydraulic fracturing, the tree-type sub-boreholes induce radial and tangential fractures that form complex fracture networks. These fracture networks can eliminate the “blank area” that may host dangerous gas pockets. Gas seepage in tree-type fractures was analyzed, and gas seepage tests after tree-type fracturing showed that permeability was greatly enhanced. The equipment developed for tree-type fracturing was tested in the Fengchun underground coal mine in China. After implementing tree-type fracturing, the gas extraction rate was around 2.3 times greater than that for traditional fracturing, and the extraction rate remained high for a long time during a 30-day test. This shortened the gas drainage time and improved gas extraction efficiency.

Gas Emission Prediction Model of Coal Mine Based on CSBP Algorithm

Directory of Open Access Journals (Sweden)

Xiong Yan

2016-01-01

Full Text Available In view of the nonlinear characteristics of gas emission in a coal working face, a prediction method is proposed based on cuckoo search algorithm optimized BP neural network (CSBP. In the CSBP algorithm, the cuckoo search is adopted to optimize weight and threshold parameters of BP network, and obtains the global optimal solutions. Furthermore, the twelve main affecting factors of the gas emission in the coal working face are taken as input vectors of CSBP algorithm, the gas emission is acted as output vector, and then the prediction model of BP neural network with optimal parameters is established. The results show that the CSBP algorithm has batter generalization ability and higher prediction accuracy, and can be utilized effectively in the prediction of coal mine gas emission.

Projected costs of generating electricity from nuclear and coal-fired power stations for commissioning in 1995

International Nuclear Information System (INIS)

1986-01-01

This report updates and extends the previous NEA study, ''The Costs of Generating Electricity in Nuclear and Coal-fired Power Stations'', published by the OECD in late 1983. Despite the changed expectations concerning coal prices and the considerable movements in exchange rates since the first study was completed, the conclusions remain essentially the same. Nuclear Power is projected to be economically superior by a significant margin to coal-fired plants for base load electricity production in Europe, Japan and some regions of North America. In areas of North America in close proximity to supplies of cheap coal, this would be the more economic fuel, unless future nuclear investment costs can be reduced to match the best US and Canadian experience. In all regions considered, the economic advantage of both coal and nuclear over oil and gas-fired plants for commissioning in the mid-1990s is expected to be substantial. These conclusions are based on an analysis of cost projections for 900 MWe to 1400 MWe Light Water Reactors to be commissioned in 1995, operating at a levelised load factor of about 72 per cent over an assumed 25 years economic life and calculated with a 5 per cent (real) discount rate. This parallels the reference reactor selected for the NEA report ''The Economics of the Nuclear Fuel Cycle'', which was published by the OECD in June 1985, though it deviates somewhat from the reference conditions of the previous generation cost study. Contemporary coal-fired stations ranging in capacity from 330 MWe to 700 MWe with the same assumed economic life and load factor provide the basis for comparison. Some data are included on CANDU Pressurised Heavy Water Reactors, and a brief comment is annexed on the relevance of the comparisons for the smaller plants that may be of interest to countries with smaller electricity networks or where special circumstances apply

Effect of temperature on the permeability of gas adsorbed coal under triaxial stress conditions

Science.gov (United States)

Li, Xiangchen; Yan, Xiaopeng; Kang, Yili

2018-04-01

The combined effects of gas sorption, stress and temperature play a significant role in the changing behavior of gas permeability in coal seams. The effect of temperature on nitrogen and methane permeability of naturally fractured coal is investigated. Coal permeability, P-wave velocity and axial strain were simultaneously measured under two effective stresses and six different temperatures. The results showed that the behavior of nitrogen and methane permeability presented nonmonotonic changes with increasing temperature. The variation in the P-wave velocity and axial strain showed a good correspondence with coal permeability. A higher effective stress limited the bigger deformation and caused the small change in permeability. Methane adsorption and desorption significantly influence the mechanical properties of coal and play an important role in the variations in coal permeability. The result of coal permeability during a complete stress-strain process showed that the variation in permeability is determined by the evolution of the internal structure. The increase in the temperature of the gas saturated coal causes the complex interaction between matrix swelling, matrix shrinkage and micro-fracture generation, which leads to the complex changes in coal structure and permeability. These results are helpful to understand the gas transport mechanism for exploiting coal methane by heat injection.

Comparative costs of coal and nuclear-generated electricity in the united states

International Nuclear Information System (INIS)

Brandfon, W.W.

1987-01-01

This paper compares the future first-year operating costs and lifetime levelized costs of producing baseload coal- and nuclear-generated electricity under schedules shorter than those recently experienced at U.S. plants. Nuclear appears to have a clear economic advantage. Coal is favorable only when it is assumed that the units will operate at very low capacity factors and/or when the capital cost differential between nuclear and coal is increased far above the recent historical level. Nuclear is therefore a cost-competitive electric energy option for utilities and should be considered as an alternative to coal when large baseload capacity is required. (author)

CFD analysis of NOx reduction by domestic natural gas added to coal combustion

Energy Technology Data Exchange (ETDEWEB)

Bar-Ziv, E.; Yasur, Y.; Chudnovsky, B. [Ben-Gurion University of the Negev, Beer-Sheva (Israel). Dept. of Mechanical Engineering and Inst. for Applied Research

2004-07-01

To date, Israel's electrical energy has been based only on imported fuels. However, with the recently discovered natural gas in the Ashqulon shores, Israel can examine the benefits to its energy resources, environment, and economy of blending its domestic natural gas with imported coal. As for using natural gas, the proposal is to burn it in existing IEC coal-fired boilers in order to significantly reduce NOx emission by reburning. An important aspect is to provide retrofitting in existing IEC boilers by replacing a fraction of the coal by natural gas. This would allow the purchase of coal with a wide range of parameters, which is less expensive. Hence, mixed gas-coal burning would benefit Israel. The authors have made numerical simulations in order to study the optimal conditions of operation and evaluate the economic as well as environmental benefits. Indeed, extensive simulations have shown that there is a significant reduction of NOx emission, as expected, with the addition of relatively small amounts of natural gas. Experiments will now be carried out in a test facility that will provide accurate physicochemical properties of the mixed fuel for more reliable simulations. 19 refs., 6 figs., 1 tab.

Can Switching from Coal to Shale Gas Bring Net Carbon Reductions to China?

Science.gov (United States)

Qin, Yue; Edwards, Ryan; Tong, Fan; Mauzerall, Denise L

2017-03-07

To increase energy security and reduce emissions of air pollutants and CO 2 from coal use, China is attempting to duplicate the rapid development of shale gas that has taken place in the United States. This work builds a framework to estimate the lifecycle greenhouse gas (GHG) emissions from China's shale gas system and compares them with GHG emissions from coal used in the power, residential, and industrial sectors. We find the mean lifecycle carbon footprint of shale gas is about 30-50% lower than that of coal in all sectors under both 20 year and 100 year global warming potentials (GWP 20 and GWP 100 ). However, primarily due to large uncertainties in methane leakage, the upper bound estimate of the lifecycle carbon footprint of shale gas in China could be approximately 15-60% higher than that of coal across sectors under GWP 20 . To ensure net GHG emission reductions when switching from coal to shale gas, we estimate the breakeven methane leakage rates to be approximately 6.0%, 7.7%, and 4.2% in the power, residential, and industrial sectors, respectively, under GWP 20 . We find shale gas in China has a good chance of delivering air quality and climate cobenefits, particularly when used in the residential sector, with proper methane leakage control.

The feasibility of underground coal gasification in developing countries with abundant coal reserves

International Nuclear Information System (INIS)

Lakay, P.; Van Den Panhuyzen, W.

1993-01-01

The feasibility of underground coal gasification is evaluated on the basis of a case study for India. India has immense coal reserves at relatively shallow depths compared to Europe, has low wages, an urgent need to expand its power capacity, a strongly rising energy demand and has shown interest in underground coal gasification. Three scenarios including the cases of continued, declining and a strong economic growth were considered. Model calculations allow to compare the cost of the electric power generated by the combustion of the gas produced by underground coal gasification with the cost of the power produced by classic thermal power plants in India for -the reference year 2000. (A.S.) 4 figs. 1 tab

Ambitious coal to gasoline plan

Energy Technology Data Exchange (ETDEWEB)

Taffe, P

1979-06-20

A design study carried out by Badger Energy concludes that the first US commercial gasoline from coal facility could be completed in eight years. The cost of gasoline would be 1.09 US dollars/gal. in 1990 with coal at 25 US dollars/ton. The process involves oxygen-blown coal gasification, conversion to methanol by the Mobil process, gas fractionation and HF alkylation.

To extract gas of the coal

International Nuclear Information System (INIS)

Carta Petrolera

2001-01-01

The paper analyzes the characteristics and advantages of extracting gas of the coal, idea that from previous years Colombia wanted to develop, and owing to the association contract Rio Rancheria; Colombia decided to carry out it using modern technologies used today in day in the international environment

Projected costs of electricity generation

International Nuclear Information System (INIS)

Cameron, R.

2010-01-01

This paper describes the outcomes of a study on the projected costs of generating electricity. It presents the latest data available on electricity generating costs for a wide variety of fuels and technologies, including coal, gas, nuclear, hydro, onshore and offshore wind, biomass, solar, wave and tidal. The study reaches 2 key conclusions. First, at a 5% real interest rate, nuclear energy is the most competitive solution for base-load electricity generation followed by coal-fired plants without carbon capture and natural gas-fired combined plants. It should be noted that coal with carbon capture has not reached a commercial phase. Second, at a 10% interest rate, nuclear remains the most competitive in Asia and North America but in Europe, coal without carbon capture equipment, followed by coal with carbon capture equipment, and gas-fired combined cycle turbines are overall more competitive than nuclear energy. The results highlight the paramount importance of interest rates (this dependence is a direct consequence of the nuclear energy's high capital costs) and of the carbon price. For instance if we assume a 10% interest rate and a cost of 50 dollar per tonne of CO 2 , nuclear energy would become competitive against both coal and gas. (A.C.)

Current developments on the coal and gas markets and their retroactive effects on the Merit Order

International Nuclear Information System (INIS)

Hecking, Harald; Cam, Eren; Schoenfisch, Max; Schulte, Simon

2017-01-01

Coal and gas continue to play a significant role in the European power generation system, especially in Germany. According to the AG energy balances, the share of hard coal in German gross electricity generation in 2016 was 17.2% and natural gas 12.4%. In addition to the CO 2 price, the prices for steam coal and natural gas are a key factor in determining which gas or coal power station is in Merit Order and whether it comes to a fuel switch. Declining gas prices have been rising sharply since the middle of 2016, and the volatile prices for steam coal have been rising. This article discusses the developments and factors responsible for these developments, which could be expected in the near future, and the implications for the gas-coal spread in the electricity market. [de

Development of standardized air-blown coal gasifier/gas turbine concepts for future electric power systems. Volume 5, Appendix D: Cost support information: Final report

Energy Technology Data Exchange (ETDEWEB)

Sadowski, R.S.; Brown, M.J.; Harriz, J.T.; Ostrowski, E.

1991-01-01

The cost estimate provided for the DOE sponsored study of Air Blown Coal Gasification was developed from vendor quotes obtained directly for the equipment needed in the 50 MW, 100 MW, and 200 MW sized plants and from quotes from other jobs that have been referenced to apply to the particular cycle. Quotes were generally obtained for the 100 MW cycle and a scale up/down factor was used to generate the cost estimates for the 200 MW and 50 MW cycles, respectively. Information from GTPro (property of Thermoflow, Inc.) was used to estimate the cost of the 200 MW and 50 MW gas turbine, HRSG, and steam turbines. To available the use of GTPro`s estimated values for this equipment, a comparison was made between the quotes obtained for the 100 MW cycle (ABB GT 11N combustion turbine and a HSRG) against the estimated values by GTPro.

Renewable vs. fossil electricity systems. A cost comparison. Power world 2050. Analysis of renewable, coal and gas-based electricity systems; Erneuerbare vs. fossile Stromsysteme. Ein Kostenvergleich. Stromwelten 2050. Analyse von Erneuerbaren, kohle- und gasbasierten Elektrizitaetssystemen

Energy Technology Data Exchange (ETDEWEB)

Graichen, Patrick; Kleiner, Mara Martha [Agora Energiewende, Berlin (Germany); Matthes, Felix Christian; Heinemann, Christoph [Oeko-Institut e.V. - Institut fuer Angewandte Oekologie, Berlin (Germany)

2017-01-15

The decarbonisation of the energy and, above all, the power system is the core component of any consistent climate protection strategy. For the electricity sector, this means, in the final analysis, the transition from a power supply based on lignite, hard coal, natural gas and other fossil fuels to one (almost) completely based on renewable energies by 2050. The fundamental technical feasibility of such a system, more than 90 percent of which would generate electricity from renewable energies, is no longer disputable today. The explanation for this is the partly rapid technological advances made in recent years, particularly those involving wind (on- and offshore) and solar energy, as well as the foreseeable further developments of central flexibility options (including flexible demand, battery storage and power-to-gas technologies). However, the question of the costs of this new electricity system has not yet been fully resolved. These cost calculations need to take into account, on the one hand, the total costs of an electricity system based on renewable energies and, on the other hand, the comparison to a power system that remains based on fossil fuels. Against this background, the present study provides a numerical analysis of the following questions: What are the technical and cost structures for a power system when 90 percent or more of the electricity is generated from renewable energies in 2050? How do the costs for different storage strategies (batteries vs. power-to-gas) differ? What technical, cost and emission structures result for a hypothetical fossil-based power system in 2050 if the further construction of electricity production plants based on wind and solar energy is immediately abandoned? How do the costs for various fossil-based power systems differ (conventional mix of lignite/hard coal/natural gas power plants vs. an electricity system based purely on natural gas)? For this purpose, a large number of model calculations with different

The production of synthetic material gas (SNG) from pit coal by a combined auto-allothermic steam gasification

International Nuclear Information System (INIS)

Buch, A.

1975-01-01

The steam gasification of pit coal requires temperatures which cannot yet be reached with the present state of HTGR technology for material technical reasons. The use of nuclear heat thus remains limited to some fields of application outside the gasifier, which are specified. The production costs of synthetic natural gas from autothermal gasification on the one hand, and from combined auto-allothermal gasification on the other hand are calculated considering the heat price of pit coal and of the selling price of electrical energy and are compared. (GG/LH) [de

Modular High Temperature Gas-Cooled Reactor heat source for coal conversion

International Nuclear Information System (INIS)

Schleicher, R.W. Jr.; Lewis, A.C.

1992-09-01

In the industrial nations, transportable fuels in the form of natural gas and petroleum derivatives constitute a primary energy source nearly equivalent to that consumed for generating electric power. Nations with large coal deposits have the option of coal conversion to meet their transportable fuel demands. But these processes themselves consume huge amounts of energy and produce undesirable combustion by-products. Therefore, this represents a major opportunity to apply nuclear energy for both the environmental and energy conservation reasons. Because the most desirable coal conversion processes take place at 800 degree C or higher, only the High Temperature Gas-Cooled Reactors (HTGRs) have the potential to be adapted to coal conversion processes. This report provides a discussion of this utilization of HTGR reactors

Coal Mine Methane in Russia

Energy Technology Data Exchange (ETDEWEB)

NONE

2009-07-01

This paper discusses coal mine methane emissions (CMM) in the Russian Federation and the potential for their productive utilisation. It highlights specific opportunities for cost-effective reductions of CMM from oil and natural gas facilities, coal mines and landfills, with the aim of improving knowledge about effective policy approaches.

Forecast and Prevention of Coal and Gas Outbursts in the Case of Application of a New Mining Method - Drilling of a Coal Pillar

Directory of Open Access Journals (Sweden)

Vlastimil Hudeček

2010-10-01

Full Text Available Coal and gas outbursts are one of risk factors accompanying the mining of coal in low seams in the Ostrava-Karviná Coalfield.At the use of the method of longwall mining, all coal reserves have not been mined out owing to tectonic faults. For mining outthe residual reserves, the application of a new mining method - drilling of a coal pillar was proposed.The method of mining of a coal seam utilizing long large diameter boreholes is verified in the Paskov Mine (company OKD, JSC –Czech Republic under conditions of rock mass with hazard of rock and gas outbursts in localities of residual pillars left in seams afterfinishing the mining operations performed with using the classical method of longwall working along the strike. [5]Forecast and preventive measures applied to the verification of the new method were based on previous experience withthe mining of seams with hazard of coal and gas outbursts. They accepted fully valid legislation, i.e. Ordinance of Ostrava RegionalMining Authority No. 3895/2002 and supplementary materials (Instructions and Guidelines. The proposed measures respectedthe character of the method being verified. [4]For all areas being mined, projects containing also chapters specifying the problems of ensuring the safety of mining worksand operation under conditions of hazard of coal and gas outbursts were prepared.In the contributions, basic proposals for the principles of coal and gas outburst forecast and prevention when applying the newmining method – drilling of a coal pillar are presented

De-linking oil and gas; The cost of Gulf gas; Middle East gas must look to Europe

International Nuclear Information System (INIS)

Aissaoui, Ali; Jensen, Jim; Stern, Jonathan

1994-01-01

This item consists of letters in response to an article by Robert Mabro on the prospects for gas in North Africa and the Middle East. The first letter is concerned with the issue of de-linking oil and gas. It is argued that the introduction of an ecotax, far from its creators' intentions, may deter investment in the natural gas industry to the benefit of coal and oil producers, rather than promoting gas as the fuel which best protects the environment. The second writer points out the Middle East's geographical disadvantage in aiming to supply natural gas to Europe. While reserves are ample, they are also readily available closer to European consumers, and without extra transportation costs. Markets nearby are either already functioning or, in areas such as India or Pakistan, prohibitively expensive in terms of pipeline construction or other technology. The last author also argues for investment in large-scale pipeline projects in order to use the Middle Eastern gas reserves, but stresses the need for political and security problems to be addressed at the same time. (UK)

Critical evaluation of high-temperature gas-cooled reactors applicable to coal conversion

International Nuclear Information System (INIS)

Spiewak, I.; Jones, J.E. Jr.; Rittenhouse, P.L.; DeStefano, J.R.; Delene, J.G.

1975-12-01

A critical review is presented of the technology and costs of very high-temperature gas-cooled reactors (VHTRs) applicable to nuclear coal conversion. Coal conversion processes suitable for coupling to reactors are described. Vendor concepts of the VHTR are summarized. The materials requirements as a function of process temperature in the range 1400 to 2000 0 F are analyzed. Components, environmental and safety factors, economics and nuclear fuel cycles are reviewed. It is concluded that process heat supply in the range 1400 to 1500 0 F could be developed with a high degree of assurance. Process heat at 1600 0 F would require considerably more materials development. While temperatures up to 2000 0 F appear to be attainable, considerably more research and risk were involved. A demonstration plant would be required as a step in the commercialization of the VHTR

Coal fired flue gas mercury emission controls

CERN Document Server

Wu, Jiang; Pan, Weiguo; Pan, Weiping

2015-01-01

Mercury (Hg) is one of the most toxic heavy metals, harmful to both the environment and human health. Hg is released into the atmosphere from natural and anthropogenic sources and its emission control has caused much concern. This book introduces readers to Hg pollution from natural and anthropogenic sources and systematically describes coal-fired flue gas mercury emission control in industry, especially from coal-fired power stations. Mercury emission control theory and experimental research are demonstrated, including how elemental mercury is oxidized into oxidized mercury and the effect of

Microporous Organic Polymers Based on Hyper-Crosslinked Coal Tar: Preparation and Application for Gas Adsorption.

Science.gov (United States)

Gao, Hui; Ding, Lei; Bai, Hua; Li, Lei

2017-02-08

Hyper-crosslinked polymers (HCPs) are promising materials for gas capture and storage, but high cost and complicated preparation limit their practical application. In this paper, a new type of HCPs (CTHPs) was synthesized through a one-step mild Friedel-Crafts reaction with low-cost coal tar as the starting material. Chloroform was utilized as both solvent and crosslinker to generate a three-dimensional crosslinked network with abundant micropores. The maximum BET surface area of the prepared CTHPs could reach up to 929 m 2  g -1 . Owing to the high affinity between the heteroatoms on the coal-tar building blocks and the CO 2 molecules, the adsorption capacity of CTHPs towards CO 2 reached up to 14.2 wt % (1.0 bar, 273 K) with a high selectivity (CO 2 /N 2 =32.3). Furthermore, the obtained CTHPs could adsorb 1.27 wt % H 2 at 1.0 bar and 77.3 K, and also showed capacity for the capture of high organic vapors at room temperature. In comparison with other reported porous organic polymers, CTHPs have the advantages of low-cost, easy preparation, and high gas-adsorption performance, making them suitable for mass production and practical use in the future. © 2017 Wiley-VCH Verlag GmbH & Co. KGaA, Weinheim.

Methanogenic pathways of coal-bed gas in the Powder River Basin, United States: The geologic factor

Energy Technology Data Exchange (ETDEWEB)

Flores, Romeo M.; Rice, Cynthia A.; Stricker, Gary D.; Warden, Augusta; Ellis, Margaret S. [U.S. Geological Survey, Box 25046, MS 939, Denver, Colorado 80225 (United States)

2008-10-02

Coal-bed gas of the Tertiary Fort Union and Wasatch Formations in the Powder River Basin in Wyoming and Montana, U.S. was interpreted as microbial in origin by previous studies based on limited data on the gas and water composition and isotopes associated with the coal beds. To fully evaluate the microbial origin of the gas and mechanisms of methane generation, additional data for 165 gas and water samples from 7 different coal-bed methane-bearing coal-bed reservoirs were collected basinwide and correlated to the coal geology and stratigraphy. The C{sub 1}/(C{sub 2} + C{sub 3}) ratio and vitrinite reflectance of coal and organic shale permitted differentiation between microbial gas and transitional thermogenic gas in the central part of the basin. Analyses of methane {delta}{sup 13}C and {delta}D, carbon dioxide {delta}{sup 13}C, and water {delta}D values indicate gas was generated primarily from microbial CO{sub 2} reduction, but with significant gas generated by microbial methyl-type fermentation (aceticlastic) in some areas of the basin. Microbial CO{sub 2} reduction occurs basinwide, but is generally dominant in Paleocene Fort Union Formation coals in the central part of the basin, whereas microbial methyl-type fermentation is common along the northwest and east margins. Isotopically light methane {delta}{sup 13}C is distributed along the basin margins where {delta}D is also depleted, indicating that both CO{sub 2}-reduction and methyl-type fermentation pathways played major roles in gas generation, but gas from the latter pathway overprinted gas from the former pathway. More specifically, along the northwest basin margin gas generation by methyl-type fermentation may have been stimulated by late-stage infiltration of groundwater recharge from clinker areas, which flowed through highly fractured and faulted coal aquifers. Also, groundwater recharge controlled a change in gas composition in the shallow Eocene Wasatch Formation with the increase of nitrogen and

Upper Paleozoic coal measures and unconventional natural gas systems of the Ordos Basin, China

Directory of Open Access Journals (Sweden)

Xuan Tang

2012-11-01

Full Text Available Upper Paleozoic coal measures in the Ordos Basin consist of dark mudstone and coal beds and are important source rocks for gas generation. Gas accumulations include coal-bed methane (CBM, tight gas and conventional gas in different structural areas. CBM accumulations are mainly distributed in the marginal area of the Ordos Basin, and are estimated at 3.5 × 1012 m3. Tight gas accumulations exist in the middle part of the Yishan Slope area, previously regarded as the basin-centered gas system and now considered as stratigraphic lithologic gas reservoirs. This paper reviews the characteristics of tight gas accumulations: poor physical properties (porosity < 8%, permeability < 0.85 × 10−3 μm2, abnormal pressure and the absence of well-defined gas water contacts. CBM is a self-generation and self-reservoir, while gas derived from coal measures migrates only for a short distance to accumulate in a tight reservoir and is termed near-generation and near-reservoir. Both CBM and tight gas systems require source rocks with a strong gas generation ability that extends together over wide area. However, the producing area of the two systems may be significantly different.

A sequential approach to control gas for the extraction of multi-gassy coal seams from traditional gas well drainage to mining-induced stress relief

International Nuclear Information System (INIS)

Kong, Shengli; Cheng, Yuanping; Ren, Ting; Liu, Hongyong

2014-01-01

Highlights: • The gas reservoirs characteristics are measured and analyzed. • A sequential approach to control gas of multi-gassy coal seams is proposed. • The design of gas drainage wells has been improved. • The utilization ways of different concentrations of gas production are shown. - Abstract: As coal resources become exhausted in shallow mines, mining operations will inevitably progress from shallow depth to deep and gassy seams due to increased demands for more coal products. However, during the extraction process of deeper and gassier coal seams, new challenges to current gas control methods have emerged, these include the conflict between the coal mine safety and the economic benefits, the difficulties in reservoirs improvement, as well as the imbalance between pre-gas drainage, roadway development and coal mining. To solve these problems, a sequential approach is introduced in this paper. Three fundamental principles are proposed: the mining-induced stress relief effect of the first-mined coalbed should be sufficient to improve the permeability of the others; the coal resource of the first-mined seams must be abundant to guarantee the economic benefits; the arrangement of the vertical wells must fit the underground mining panel. Tunlan coal mine is taken as a typical example to demonstrate the effectiveness of this approach. The approach of integrating surface coalbed methane (CBM) exploitation with underground gas control technologies brings three major benefits: the improvement of underground coal mining safety, the implementation of CBM extraction, and the reduction of greenhouse gas emissions. This practice could be used as a valuable example for other coal mines having similar geological conditions

Secondary biogenic coal seam gas reservoirs in New Zealand: A preliminary assessment of gas contents

Energy Technology Data Exchange (ETDEWEB)

Butland, Carol I. [Department of Geological Sciences, University of Canterbury, Private Bag 4800, Christchurch (New Zealand); Moore, Tim A. [Department of Geological Sciences, University of Canterbury, Private Bag 4800, Christchurch (New Zealand); Solid Energy NZ Ltd., P.O. Box 1303, Christchurch (New Zealand)

2008-10-02

Four coal cores, one from the Huntly (Eocene), two from the Ohai (Cretaceous) and one from the Greymouth (Cretaceous) coalfields, were sampled and analysed in terms of gas content and coal properties. The coals vary in rank from subbituminous B-A (Huntly) to subbituminous C-A (Ohai), and high volatile A bituminous (Greymouth). Average gas contents were 1.60 m{sup 3}/t (s 0.2) in the Huntly core, 4.80 m{sup 3}/t (s = 0.8) in the Ohai cores, and 2.39 m{sup 3}/t (s = 0.8) in the Greymouth core. The Ohai core not only contained more gas but also had the highest saturation (75%) compared with the Huntly (33%) and Greymouth (45%) cores. Carbon isotopes indicate that the Ohai gas is more mature, containing higher {delta}{sup 13}C isotopes values than either the Huntly or Greymouth gas samples. This may indicate that the gas was derived from a mixed biogenic and thermogenic source. The Huntly and Greymouth gases appear to be derived solely from a secondary biogenic (by CO{sub 2} reduction) source. Although the data set is limited, preliminary analysis indicates that ash yield is the dominant control on gas volume in all samples where the ash yield was above 10%. Below 10%, the amount of gas variation is unrelated to ash yield. Although organic content has some influence on gas volume, associations are basin and/or rank dependent. In the Huntly core total gas content and structured vitrinite increase together. Although this relationship does not appear for the other core data for the Ohai SC3 core, lost gas and fusinite are associated whereas gelovitrinite (unstructured vitrinite) correlates positively with residual gas for the Greymouth data. (author)

Nuclear energy cost data base: A reference data base for nuclear and coal-fired powerplant power generation cost analysis

International Nuclear Information System (INIS)

1988-09-01

A reference data base and standard methodology are needed for performing comparative nuclear and fossil power generation cost analyses for the Department of Energy, Office of Nuclear Energy. This report contains such a methodology together with reference assumptions and data to be used with the methodology. It is intended to provide basic guidelines or a starting point for analyses and to serve as a focal point in establishing parameters and methods to be used in economic comparisons of nuclear systems with alternatives. The data base is applicable for economic comparisons of new base load light-water reactors on a once-through cycle, and high- and low-sulfur coal-fired plants, and oil- and natural gas-fired electric generating plants coming on line around the turn of the century. In addition to current generation light-water reactors and fossil fuel-fired plants, preliminary cost information is also presented on improved and advanced light-water reactors, liquid metal reactor plants and fuel cycle facilities. This report includes an updated data base containing proposed technical and economic assumptions to be used in analyses, discussions of a recommended methodology to be used in calculating power generation costs, a sample calculation for illustrative and benchmark purposes and projected power generation costs for fission and coal-fired alternatives. Effects of the 1986 Tax Reform Act are included. 126 refs., 17 figs., 47 tabs

Gasification of coal with steam using heat from HTRs

International Nuclear Information System (INIS)

Juentgen, H.; Heek, K.H. van

1975-01-01

In existing coal gasification processes a substantial part of the coal is used to provide the heat for the reaction, for the generation and superheating of steam and for the production of oxygen. By using heat from HTRs to substitute this part, the coal is then completely used as raw material for gas production. This offers the following advantages compared with the existing processes: a saving of coal, less CO 2 emission and, in countries with high coal costs, lower gas production costs. A survey is given of the state of the project, discussing the first design of a commercial gasifier, the influence of the helium outlet temperature of the HTR, kinds of products, and the overall efficiency of the plant. The aim of the development is to demonstrate the use of heat from an HTR for full scale coal gasification, starting in 1985. (Auth.)

Comparison of costs of electricity generation based on nuclear energy and pit coal

International Nuclear Information System (INIS)

1981-01-01

Despite of a meanwhile considerable increase in costs of installation, especially of nuclear power stations, the differences in costs have increased in favour of nuclear electricity generation. The cost advantages are estimated 4 German Pfennig per kilowatt-hour in the base-load field for plants coming into operation at the end of this decade compared with the most profitable variant of pit coal utilization on which this investigation is based; compared to the use of German hard coal, assuming a relatively optimistic development of prices for domestic hard coal in the future, the cost advantage is estimated 8 German Pfennig per kilowatt-hour. The main reason is that in the past years the price for German hard coal as well as for imported coal considerably rose and for the future further increases have to be expected whereas the largest share of the costs of nuclear electricity generation doesn't increase, after the plant is completed. Considering the importance of the fuel costs within the total costs of electricity generation in coal power stations this must have its effects on the total result. These results also prove to be valid for a variation of important cost parameters. Only if the unlikely assumption that considerable variations of influences on costs - each unfavourable effecting nuclear electricity generation - would come together would prove to be true the economic efficiency of nuclear energy would be reduced or questioned. (UA) [de

A LOW COST AND HIGH QUALITY SOLID FUEL FROM BIOMASS AND COAL FINES

Energy Technology Data Exchange (ETDEWEB)

John T. Kelly; George Miller; Mehdi Namazian

2001-07-01

Use of biomass wastes as fuels in existing boilers would reduce greenhouse gas emissions, SO2 and NOx emissions, while beneficially utilizing wastes. However, the use of biomass has been limited by its low energy content and density, high moisture content, inconsistent configuration and decay characteristics. If biomass is upgraded by conventional methods, the cost of the fuel becomes prohibitive. Altex has identified a process, called the Altex Fuel Pellet (AFP) process, that utilizes a mixture of biomass wastes, including municipal biosolids, and some coal fines, to produce a strong, high energy content, good burning and weather resistant fuel pellet, that is lower in cost than coal. This cost benefit is primarily derived from fees that are collected for accepting municipal biosolids. Besides low cost, the process is also flexible and can incorporate several biomass materials of interest The work reported on herein showed the technical and economic feasibility of the AFP process. Low-cost sawdust wood waste and light fractions of municipal wastes were selected as key biomass wastes to be combined with biosolids and coal fines to produce AFP pellets. The process combines steps of dewatering, pellet extrusion, drying and weatherizing. Prior to pilot-scale tests, bench-scale test equipment was used to produce limited quantities of pellets for characterization. These tests showed which pellet formulations had a high potential. Pilot-scale tests then showed that extremely robust pellets could be produced that have high energy content, good density and adequate weatherability. It was concluded that these pellets could be handled, stored and transported using equipment similar to that used for coal. Tests showed that AFP pellets have a high combustion rate when burned in a stoker type systems. While NOx emissions under stoker type firing conditions was high, a simple air staging approach reduced emissions to below that for coal. In pulverized-fuel-fired tests it was

Deregulated gas in 1985 seen costly

Energy Technology Data Exchange (ETDEWEB)

Schaffer, P.

1980-05-05

Deregulation of natural gas wellhead prices will mean higher prices for nonboiler industrial users, according to an Energy and Environmental Analysis Inc. (EEA) study. The price increases of high-sulfur residual fuel oil will exceed inflation rates, but low-sulfur residual oil and distillate oil will have smaller increases because of upgraded refineries. Te economc imact analysis is broken down by region and includes estimates of gas, high-sulfur coal, and low-sulfur coal prices thrugh 1995. Free copies of the report are available from the Federal Energy Regulatory Commission's Office of Public Information. (DCK)

KINETICS OF DIRECT OXIDATION OF H2S IN COAL GAS TO ELEMENTAL SULFUR; F

International Nuclear Information System (INIS)

K.C. Kwon

2002-01-01

Removal of hydrogen sulfide (H(sub 2)S) from coal gasifier gas and sulfur recovery are key steps in the development of Department of Energy's (DOE's) advanced Vision 21 plants that employ coal and natural gas and produce electric power and clean transportation fuels. These Vision 21 plants will require highly clean coal gas with H(sub 2)S below 1 ppm and negligible amounts of trace contaminants such as hydrogen chloride, ammonia, alkali, heavy metals, and particulate. The conventional method of sulfur removal and recovery employing amine, Claus, and tail-gas treatment is very expensive. A second generation approach developed under DOE's sponsorship employs hot-gas desulfurization (HGD) using regenerable metal oxide sorbents followed by Direct Sulfur Recovery Process (DSRP). However, this process sequence does not remove trace contaminants and is targeted primarily towards the development of advanced integrated gasification combined cycle (IGCC) plants that produce electricity (not both electricity and transportation fuels). There is an immediate as well as long-term need for the development of cleanup processes that produce highly clean coal gas for next generation Vision 21 plants. To this end, a novel process is now under development at Research Triangle Institute (RTI) in which the H(sub 2)S in coal gas is directly oxidized to elemental sulfur over a selective catalyst. Such a process is ideally suited for coal gas from commercial gasifiers with a quench system to remove essentially all the trace contaminants except H(sub 2)S. This direct oxidation process has the potential to produce a super clean coal gas more economically than both conventional amine-based processes and HGD/DSRP. The objective of this research is to support the near- and long-term DOE efforts to commercialize this direct oxidation technology. Specifically, we aim to: Measure the kinetics of direct oxidation of H(sub 2)S to elemental sulfur over selective catalysts in the presence of major

Biogeochemical interactions between of coal mine water and gas well cement

Science.gov (United States)

Gulliver, D. M.; Gardiner, J. B.; Kutchko, B. G.; Hakala, A.; Spaulding, R.; Tkach, M. K.; Ross, D.

2017-12-01

Unconventional natural gas wells drilled in Northern Appalachia often pass through abandoned coal mines before reaching the Marcellus or Utica formations. Biogeochemical interactions between coal mine waters and gas well cements have the potential to alter the cement and compromise its sealing integrity. This study investigates the mineralogical, geochemical, and microbial changes of cement cores exposed to natural coal mine waters. Static reactors with Class H Portland cement cores and water samples from an abandoned bituminous Pittsburgh coal mine simulated the cement-fluid interactions at relevant temperature for time periods of 1, 2, 4, and 6 weeks. Fluids were analyzed for cation and anion concentrations and extracted DNA was analyzed by 16S rRNA gene sequencing and shotgun sequencing. Cement core material was evaluated via scanning electron microscope. Results suggest that the sampled coal mine water altered the permeability and matrix mineralogy of the cement cores. Scanning electron microscope images display an increase in mineral precipitates inside the cement matrix over the course of the experiment. Chemistry results from the reaction vessels' effluent waters display decreases in dissolved calcium, iron, silica, chloride, and sulfate. The microbial community decreased in diversity over the 6-week experiment, with Hydrogenophaga emerging as dominant. These results provide insight in the complex microbial-fluid-mineral interactions of these environments. This study begins to characterize the rarely documented biogeochemical impacts that coal waters may have on unconventional gas well integrity.

Coal liquefaction and gas conversion: Proceedings. Volume 1

Energy Technology Data Exchange (ETDEWEB)

1993-12-31

Volume I contains papers presented at the following sessions: AR-Coal Liquefaction; Gas to Liquids; and Direct Liquefaction. Selected papers have been processed separately for inclusion in the Energy Science and Technology Database.

The role of natural gas as a primary fuel in the near future, including comparisons of acquisition, transmission and waste handling costs of as with competitive alternatives

Science.gov (United States)

2012-01-01

Natural gas comprises about a quarter of the United States’ energy use. It is more environmentally friendly than oil and coal due to lower carbon dioxide (CO2) emissions per unit, less costly per unit of energy and more readily available domestically in abundant supply. However, due to a number of barriers in the political, infrastructural, pricing and other arenas, the use of natural gas as a significant energy source in the United States has been limited. In our paper, we highlight the favorable qualities of natural gas and its benefits for the consumer, producer, and environment, having compared the costs of the various components of the natural gas business such as drilling and transport to that of coal and oil. Moreover, we touch upon the major issues that have prevented a more prevalent use of the gas, such as the fact that the infrastructure of natural gas is more costly since it is transported though pipelines whereas other energy sources such as oil and coal have flexible systems that use trains, trucks and ships. In addition, the powerful lobbies of the coal and oil businesses, along with the inertia in the congress to pass a national climate change bill further dampens incentives for these industries to invest in natural gas, despite its various attractive qualities. We also include discussions of policy proposals to incentive greater use of natural gas in the future. PMID:22540989

The Imposition Environmental Cost-Loading Of Companies Investing In Coal Mining

Directory of Open Access Journals (Sweden)

Tomi Risman

2015-08-01

Full Text Available The instrument of environment is an effort to prevent environmental problems caused by mining activities both in forms and its nature. The aims of the study are to analyze and understanding the essence of environment cost-loading in order to restore the environment from coal mining activities both when mining taken place and post-mining. The type of research used is a normative-legal research. This research was conducted in the province of South Kalimantan with the consideration that the South Kalimantan is one of the largest coal-producing Provinces in Indonesia. In addition the environment cost-loading for investor in coal mining have the same properties in all coal mining sites in Indonesia. The results of the research indicated that the imposition and environment-cost in investment activity in the field of coal mining can be seen from the two approaches i.e the economic and legal approach. Economic approach is an approach that emphasizes the economic benefits gained by the owner of activities when they comply with the environmental requirements stipulated by laws and environmental regulations. Realizing the importance of environmental cost-loading for the company that manages the coal mining especially for the utilization of prevention of pollution caused by coal mining activity it is necessary to develop an institutional guarantee of recovery from the effects of pollution by establishing fund insurance for environmental restoration as a result of pollution. Thus in order to optimize the implementation of guarantee fund for environmental restoration are specifically utilized for post-mining reclamation then granting the status of Clean and Clear C amp C for coal mining investor must be presupposing the proof of guarantee fund has been placed for environmental restoration post-mining.

Determination of coalbed methane potential and gas adsorption capacity in Western Kentucky coals

Science.gov (United States)

Mardon, S.M.; Takacs, K.G.; Hower, J.C.; Eble, C.F.; Mastalerz, Maria

2006-01-01

The Illinois Basin has not been developed for Coalbed Methane (CBM) production. It is imperative to determine both gas content and other parameters for the Kentucky portion of the Illinois Basin if exploration is to progress and production is to occur in this area. This research is part of a larger project being conducted by the Kentucky Geological Survey to evaluate the CBM production of Pennsylvanian-age western Kentucky coals in Ohio, Webster, and Union counties using methane adsorption isotherms, direct gas desorption measurements, and chemical analyses of coal and gas. This research will investigate relationships between CBM potential and petrographic, surface area, pore size, and gas adsorption isotherm analyses of the coals. Maceral and reflectance analyses are being conducted at the Center for Applied Energy Research. At the Indiana Geological Survey, the surface area and pore size of the coals will be analyzed using a Micrometrics ASAP 2020, and the CO2 isotherm analyses will be conducted using a volumetric adsorption apparatus in a water temperature bath. The aforementioned analyses will be used to determine site specific correlations for the Kentucky part of the Illinois Basin. The data collected will be compared with previous work in the Illinois Basin and will be correlated with data and structural features in the basin. Gas composition and carbon and hydrogen isotopic data suggest mostly thermogenic origin of coalbed gas in coals from Webster and Union Counties, Kentucky, in contrast to the dominantly biogenic character of coalbed gas in Ohio County, Kentucky.

Low Cost, High Capacity Regenerable Sorbent for Carbon Dioxide Capture from Existing Coal-fired Power Plants

Energy Technology Data Exchange (ETDEWEB)

Alptekin, Gokhan [TDA Research, Inc., Wheat Ridge, CO (United States); Jayaraman, Ambalavanan [TDA Research, Inc., Wheat Ridge, CO (United States); Dietz, Steven [TDA Research, Inc., Wheat Ridge, CO (United States)

2016-03-03

In this project TDA Research, Inc (TDA) has developed a new post combustion carbon capture technology based on a vacuum swing adsorption system that uses a steam purge and demonstrated its technical feasibility and economic viability in laboratory-scale tests and tests in actual coal derived flue gas. TDA uses an advanced physical adsorbent to selectively remove CO₂ from the flue gas. The sorbent exhibits a much higher affinity for CO₂ than N₂, H₂O or O₂, enabling effective CO₂ separation from the flue gas. We also carried out a detailed process design and analysis of the new system as part of both sub-critical and super-critical pulverized coal fired power plants. The new technology uses a low cost, high capacity adsorbent that selectively removes CO₂ in the presence of moisture at the flue gas temperature without a need for significant cooling of the flue gas or moisture removal. The sorbent is based on a TDA proprietary mesoporous carbon that consists of surface functionalized groups that remove CO₂ via physical adsorption. The high surface area and favorable porosity of the sorbent also provides a unique platform to introduce additional functionality, such as active groups to remove trace metals (e.g., Hg, As). In collaboration with the Advanced Power and Energy Program of the University of California, Irvine (UCI), TDA developed system simulation models using Aspen PlusTM simulation software to assess the economic viability of TDA’s VSA-based post-combustion carbon capture technology. The levelized cost of electricity including the TS&M costs for CO₂ is calculated as $116.71/MWh and $113.76/MWh for TDA system integrated with sub-critical and super-critical pulverized coal fired power plants; much lower than the $153.03/MWhand $147.44/MWh calculated for the corresponding amine based systems. The cost of CO₂ captured for TDA’s VSA based system is $38

Cost structure of coal- and nuclear-fired electric power plants

International Nuclear Information System (INIS)

Helmuth, J.A.

1981-01-01

This dissertation investigates the cost structure of coal and nuclear electric power generation. The emphasis of the paper is to empirically estimate the direct costs of generating base-load electric power at the plant level. Empirically, the paper first investigates the relative comparative costs of nuclear and coal power generation, based on historical operating data. Consideration of the learning curve and other dynamic elements is incorporated in the analysis. The second empirical thrust is to inestigate economies of scale for both technologies. The results from the empirical studies give an indication as to the future and present cost viability of each technology. Implications toward energy policy are discussed

Coal fired air turbine cogeneration

Science.gov (United States)

Foster-Pegg, R. W.

Fuel options and generator configurations for installation of cogenerator equipment are reviewed, noting that the use of oil or gas may be precluded by cost or legislation within the lifetime of any cogeneration equipment yet to be installed. A coal fueled air turbine cogenerator plant is described, which uses external combustion in a limestone bed at atmospheric pressure and in which air tubes are sunk to gain heat for a gas turbine. The limestone in the 26 MW unit absorbs sulfur from the coal, and can be replaced by other sorbents depending on types of coal available and stringency of local environmental regulations. Low temperature combustion reduces NOx formation and release of alkali salts and corrosion. The air heat is exhausted through a heat recovery boiler to produce process steam, then can be refed into the combustion chamber to satisfy preheat requirements. All parts of the cogenerator are designed to withstand full combustion temperature (1500 F) in the event of air flow stoppage. Costs are compared with those of a coal fired boiler and purchased power, and it is shown that the increased capital requirements for cogenerator apparatus will yield a 2.8 year payback. Detailed flow charts, diagrams and costs schedules are included.

Development of coal hydro gasification technology

International Nuclear Information System (INIS)

Itoh, Kazuo; Nomura, Kazuo; Asaoka, Yoshikiyo; Kato, Shojiro; Seo, Tomoyuki

1997-01-01

Taking a potential future decrease in natural gas supply into consideration, we are looking for a way to secure a stable supply of high quality substitute natural gas made from coal (which occurs abundantly throughout the world) in large volumes at low cost. We are working towards our goal of commercializing coal hydro gasification technology in the 2010's and have started developing elemental technology from FY, 1996 as a part of the governmental new energy program. (au)

Costs of abandoned coal mine reclamation and associated recreation benefits in Ohio.

Science.gov (United States)

Mishra, Shruti K; Hitzhusen, Frederick J; Sohngen, Brent L; Guldmann, Jean-Michel

2012-06-15

Two hundred years of coal mining in Ohio have degraded land and water resources, imposing social costs on its citizens. An interdisciplinary approach employing hydrology, geographic information systems, and a recreation visitation function model, is used to estimate the damages from upstream coal mining to lakes in Ohio. The estimated recreational damages to five of the coal-mining-impacted lakes, using dissolved sulfate as coal-mining-impact indicator, amount to $21 Million per year. Post-reclamation recreational benefits from reducing sulfate concentrations by 6.5% and 15% in the five impacted lakes were estimated to range from $1.89 to $4.92 Million per year, with a net present value ranging from $14.56 Million to $37.79 Million. A benefit costs analysis (BCA) of recreational benefits and coal mine reclamation costs provides some evidence for potential Pareto improvement by investing limited resources in reclamation projects. Copyright © 2012 Elsevier Ltd. All rights reserved.

Portable rapid gas content measurement - an opportunity for a step change in the coal industry?

International Nuclear Information System (INIS)

Beamish, Basil; Kizil, Mehmet; Gu, Ming

2013-01-01

The last major advance in gas content measurement for coal seams was the introduction of the quick crush technique in the early 1990s. This is a laboratory test method that has proven very reliable over the years. Recent laboratory testing using a portable quick crushing device, known as the portable gas content analyser, has produced consistent gas content results for a set of core samples obtained from a single borehole that intersected four coal seams. The retained gas content values obtained for the seams show the same increasing gas content pattern and gas composition change with depth as the standard quick crush technique. Use of the portable gas content analyser provides the opportunity to produce rapid, reliable gas content measurement of coal that could be developed for assessing gas compliance cores and outburst-prone conditions at a mine site.

Integrated petrographic and geochemical study of coal and gas shales from the Sabinas and Chihuahua basins, North of Mexico: estimation of methane gas resources

International Nuclear Information System (INIS)

De La O Burrola, Francisco

2013-01-01

This comprehensive characterization study was performed using organic petrology and geochemistry conducted in the Sabinas basin and Chihuahua in northern Mexico. This information allowed a numerical modeling of gas formation, considering the thermal subsidence of coal and carbonaceous shales. The objectives of this thesis are: - Establish a characterization methodology for the studied rocks - Estimate potential gas generator and its regional distribution - Estimate the methane gas resources For the development of this project, we conducted an intensive campaign representative sampling of coal, carbonaceous shales and coal gas 'in situ'. For the Sabinas basin were studied 97 samples and 114 samples in the basin of Chihuahua. The analyses carried out that were used on the samples analyzed allowed to characterize the kerogen and gas. The methodology used to cross petrographic and geochemical information to analyze the petroleum system by numerical modeling. Analyses were: Petrographic, reflectance %Ro, elemental analysis and immediate, Rock Eval6 R (Bulk rock), isotopic analysis, δ 13 C, δD, (coal gas), scanning electron microscopy, image analysis and analysis of macerals fluid inclusions. The analyzes that were used on the samples allowed to characterize the sample, the kerogen and gas. The methodology used to cross petrographic and geochemical information for analyze the oil system by numerical modeling. Analyses were: Petrographic, reflectance %Ro, elemental analysis and immediate, Rock Eval6 R (Bulk rock), isotopic analysis, δ 13 C, δD, (coal gas), scanning electron microscopy, image analysis and analysis of macerals fluid inclusions A computer program was constructed to cross the information with the analysis of samples of artificial maturation experiments in the laboratory. This approach allowed estimation of methane gas resources generated by coal and carbonaceous shales. The main results obtained for Sabinas Basin were: - The kerogen of the

Thermochemical Equilibrium Model of Synthetic Natural Gas Production from Coal Gasification Using Aspen Plus

Directory of Open Access Journals (Sweden)

Rolando Barrera

2014-01-01

Full Text Available The production of synthetic or substitute natural gas (SNG from coal is a process of interest in Colombia where the reserves-to-production ratio (R/P for natural gas is expected to be between 7 and 10 years, while the R/P for coal is forecasted to be around 90 years. In this work, the process to produce SNG by means of coal-entrained flow gasifiers is modeled under thermochemical equilibrium with the Gibbs free energy approach. The model was developed using a complete and comprehensive Aspen Plus model. Two typical technologies used in entrained flow gasifiers such as coal dry and coal slurry are modeled and simulated. Emphasis is put on interactions between the fuel feeding technology and selected energy output parameters of coal-SNG process, that is, energy efficiencies, power, and SNG quality. It was found that coal rank does not significantly affect energy indicators such as cold gas, process, and global efficiencies. However, feeding technology clearly has an effect on the process due to the gasifying agent. Simulations results are compared against available technical data with good accuracy. Thus, the proposed model is considered as a versatile and useful computational tool to study and optimize the coal to SNG process.

Coupling Effect of Intruding Water and Inherent Gas on Coal Strength Based on the Improved (Mohr-Coulomb Failure Criterion

Directory of Open Access Journals (Sweden)

Yiyu Lu

2016-11-01

Full Text Available When employing hydraulic processes to increase gas drainage efficiency in underground coal mines, coal seams become a three-phase medium, containing water intruding into the coal pores with the inherent occurrence of gas. This can change the stress state of the coal and cause instability. This work studied the mechanical properties of coal containing water and gas and derived an appropriate failure criterion. Based on mixture theory of unsaturated porous media, the effective stress of coal, considering the interaction of water and gas, was analyzed, and the failure criterion established by combining this with the Mohr–Coulomb criterion. By introducing the stress factor of matrix suction and using fitted curves of experimentally determined matrix suction and moisture content, the relationships between coal strength, gas pressure, and moisture content were determined. To verify the established strength theory, a series of triaxial compression strength tests of coal containing water and gas were carried out on samples taken from the Songzao, Pingdingshan, and Tashan mines in China. The experimental results correlated well with the theoretical predictions. The results showed a linear decrease in the peak strength of coal with increasing gas pressure and an exponential reduction in peak strength with increasing moisture content. The strength theory of coal containing water and gas can become an important part of multiphase medium damage theory.

A new method for calculating gas content of coal reservoirs with consideration of a micro-pore overpressure environment

Directory of Open Access Journals (Sweden)

Jinxing Song

2017-05-01

Full Text Available When the gas content of a coal reservoir is calculated, the reservoir pressure measured by well logging and well testing is generally used for inversion calculation instead of gas pressure. However, the calculation result is not accurate because the reservoir pressure is not equal to the gas pressure in overpressure environments. In this paper, coal samples of different ranks in Shanxi and Henan are collected for testing the capillary pressure of coal pores. Based on the formation process of CBM reservoirs and the hydrocarbon generation and expulsion history of coal beds, the forming mechanisms of micro-pore overpressure environments in coal reservoirs were analyzed. Accordingly, a new method for calculating the gas content of coal reservoirs with consideration of a micro-pore overpressure environment was developed. And it was used to calculate the gas content of No. 1 coal bed of the 2nd member of Lower Permian Shanxi Fm in the Zhongmacun Coal Mine in Jiaozuo, Henan. It is indicated that during the formation and evolution of coals, some solid organic matters were converted into gas and water, and gas–water contact is surely formed in pores. In the end, capillary pressure is generated, so the gas pressure in micro-pores is much higher than the hydrostatic column pressure, which results in a micro-pore overpressure environment. Under such an environment, gas pressure is higher than reservoir pressure, so the gas content of coal reservoirs calculated previously based on the conventional reservoir pressure evaluation are usually underestimated. It is also found that the micro-pore overpressure environment exerts a dominating effect on the CBM content calculation of 3–100 nm pores, especially that of 3–10 nm pores, but a little effect on that of pores >100 nm. In conclusion, this new method clarifies the pressure environment of CBM gas reservoirs, thereby ensuring the calculation accuracy of gas content of coal reservoirs.

Evaluation of gasification and gas cleanup processes for use in molten carbonate fuel cell power plants. Final report. [Contains lists and evaluations of coal gasification and fuel gas desulfurization processes

Energy Technology Data Exchange (ETDEWEB)

Jablonski, G.; Hamm, J.R.; Alvin, M.A.; Wenglarz, R.A.; Patel, P.

1982-01-01

This report satisfies the requirements for DOE Contract AC21-81MC16220 to: List coal gasifiers and gas cleanup systems suitable for supplying fuel to molten carbonate fuel cells (MCFC) in industrial and utility power plants; extensively characterize those coal gas cleanup systems rejected by DOE's MCFC contractors for their power plant systems by virtue of the resources required for those systems to be commercially developed; develop an analytical model to predict MCFC tolerance for particulates on the anode (fuel gas) side of the MCFC; develop an analytical model to predict MCFC anode side tolerance for chemical species, including sulfides, halogens, and trace heavy metals; choose from the candidate gasifier/cleanup systems those most suitable for MCFC-based power plants; choose a reference wet cleanup system; provide parametric analyses of the coal gasifiers and gas cleanup systems when integrated into a power plant incorporating MCFC units with suitable gas expansion turbines, steam turbines, heat exchangers, and heat recovery steam generators, using the Westinghouse proprietary AHEAD computer model; provide efficiency, investment, cost of electricity, operability, and environmental effect rankings of the system; and provide a final report incorporating the results of all of the above tasks. Section 7 of this final report provides general conclusions.

Measurements of Gasification Characteristics of Coal and Char in CO2-Rich Gas Flow by TG-DTA

Directory of Open Access Journals (Sweden)

Zhigang Li

2013-01-01

Full Text Available Pyrolysis, combustion, and gasification properties of pulverized coal and char in CO2-rich gas flow were investigated by using gravimetric-differential thermal analysis (TG-DTA with changing O2%, heating temperature gradient, and flow rate of CO2-rich gases provided. Together with TG-DTA, flue gas generated from the heated coal, such as CO, CO2, and hydrocarbons (HCs, was analyzed simultaneously on the heating process. The optimum O2% in CO2-rich gas for combustion and gasification of coal or char was discussed by analyzing flue gas with changing O2 from 0 to 5%. The experimental results indicate that O2% has an especially large effect on carbon oxidation at temperature less than 1100°C, and lower O2 concentration promotes gasification reaction by producing CO gas over 1100°C in temperature. The TG-DTA results with gas analyses have presented basic reference data that show the effects of O2 concentration and heating rate on coal physical and chemical behaviors for the expected technologies on coal gasification in CO2-rich gas and oxygen combustion and underground coal gasification.

Gas, electricity, coal: 1998 statistical data

International Nuclear Information System (INIS)

1999-01-01

This document brings together the main statistical data from the French direction of gas, electricity and coal and presents a selection of the most significant numbered data: origin of production, share of the consumption, price levels, resources-employment status. These data are presented in a synthetic and accessible way in order to make useful references for the actors of the energy sector. (J.S.)

Dynamic simulation model of a coal thermoelectric plant with a flue gas desulphurisation system

International Nuclear Information System (INIS)

Caselles-Moncho, Antonio; Ferrandiz-Serrano, Liliana; Peris-Mora, Eduardo

2006-01-01

In this paper a Dynamic Simulation Model has been used to present the likely responses of the electricity industries' latest perturbations such as: changes in environmental regulations, international fuel market evolution, restriction on fuel supply and increase on fuel prices, liberalisation of the European Electricity Market, and the results of applying energy policies and official tools such as taxes and emission allowances. The case under study refers to the Teruel Power Plant, built after the 1970s oil crisis to ensure national electricity supply; burning domestically produced coal in order to ensure local mining activity. The Teruel Power Plant has made relevant investments in order to meet emission limits, such as a Flue Gas Desulphurisation Plant. The economic viability of the power stations has to be analysed after environmental costs have been internalised. A system is defined that studies the coal-firing Electric Power Plant selling energy to the free electricity market, whenever the generation cost is competitive. A Dynamic Simulation Model would appear to be an accurate tool to optimise power station management within different frameworks

Underground Coal Gasification: Rates of Post Processing Gas Transport

Czech Academy of Sciences Publication Activity Database

Soukup, Karel; Hejtmánek, Vladimír; Stanczyk, K.; Šolcová, Olga

2014-01-01

Roč. 68, č. 12 (2014), s. 1707-1715 ISSN 0366-6352 R&D Projects: GA MŠk 7C12017 Grant - others:RFCS(XE) RFCR-CT-2011-00002 Institutional support: RVO:67985858 Keywords : underground coal gas ification * gas transport * textural properties Subject RIV: CI - Industrial Chemistry, Chemical Engineering Impact factor: 1.468, year: 2014

Income risk of EU coal-fired power plants after Kyoto

International Nuclear Information System (INIS)

Abadie, Luis M.; Chamorro, Jose M.

2009-01-01

Coal-fired power plants enjoy a significant advantage relative to gas plants in terms of cheaper fuel cost. This advantage may erode (or turn into disadvantage) depending on CO 2 emission allowance price. Financial risks are further reinforced when the price of electricity is determined by natural gas-fired plants' marginal costs. We aim to empirically assess the risks in EU coal plants' margins up to the year 2020. Parameter values are derived from actual market data. Monte Carlo simulation allows compute the expected value and risk profile of coal plants' earnings. Future allowance prices may spell significant risks on utilities' balance sheets. (author)

Staged fluidized-bed coal combustor for boiler retrofit

International Nuclear Information System (INIS)

Rehmat, A.; Dorfman, L.; Shibayama, G.; Waibel, R.

1991-01-01

The Advanced Staged Fluidized-Bed Coal Combustion System (ASC) is a novel clean coal technology for either coal-fired repowering of existing boilers or for incremental power generation using combined-cycle gas turbines. This new technology combines staged combustion for gaseous emission control, in-situ sulfur capture, and an ash agglomeration/vitrification process for the agglomeration/vitrification of ash and spent sorbent, thus rendering solid waste environmentally benign. The market for ASC is expected to be for clean coal-fired repowering of generating units up to 250 MW, especially for units where space is limited. The expected tightening of the environmental requirements on leachable solids residue by-products could considerably increase the marketability for ASC. ASC consists of modular low-pressure vessels in which coal is partially combusted and gasified using stacked fluidized-bed processes to produce low-to-medium-Btu, high-temperature gas. This relatively clean fuel gas is used to repower/refuel existing pulverized-coal, natural gas, or oil-fired boilers using bottom firing and reburning techniques. The benefits of ASC coal-fired repowering include the ability to repower boilers without obtaining additional space while meeting the more stringent environmental requirements of the future. Low NO x , SO x , and particulate levels are expected while a nonleachable solid residue with trace metal encapsulation is produced. ASC also minimizes boiler modification and life-extension expenditures. Repowered efficiencies can be restored to the initial operating plant efficiency, and the existing boiler capacity can be increased by 10%. Preliminary cost estimates indicate that ASC will have up to a $250/kW capital cost advantage over existing coal-fired repowering options. 4 figs., 4 tabs

Study on the propagation law of shock wave resulting from coal and gas outburst

Institute of Scientific and Technical Information of China (English)

WANG Kai; ZHOU Ai-tao; ZHANG Pin; LI Chuan; GUO Yan-wei

2011-01-01

According to the formation of shock wave resulting from coal and gas outburst, the gas flow of coal and gas outburst was transformed from an unsteady flow to a steady one based on selected appropriate reference coordinates, and the mathematical expressions were then established by applying mass conservation, momentum conservation equation, and energy conservation equation. On this basis, analyzed gas flow mitigation of variable cross-section area and the outburst intensity, and the relations between cross-section area, velocity, and density; the relations between overpressures and outburst intensity were deduced. Furthermore, shock waves resulting from coal and gas outburst and outburst intensity were measured by experimental setup, the overpressure and outburst intensity of different gas pressures were obtained, and the similar conditions of the experiment were numerically simulated. The averaged overpressure and gas flow velocity of variable cross-section under different gas pressures were numerically derived. The results show that the averaged overpressure and outburst intensity obtained from simulation are in good agreement with the experimental results. Moreover, the gas flow velocity of variable cross-sections approximates to the theoretical analysis.

Coal Mine Methane in Russia [Russian Version

Energy Technology Data Exchange (ETDEWEB)

NONE

2010-07-01

This paper discusses coal mine methane emissions (CMM) in the Russian Federation and the potential for their productive utilisation. It highlights specific opportunities for cost-effective reductions of CMM from oil and natural gas facilities, coal mines and landfills, with the aim of improving knowledge about effective policy approaches.

Shell coal IGCCS with carbon capture: Conventional gas quench vs. innovative configurations

International Nuclear Information System (INIS)

Martelli, Emanuele; Kreutz, Thomas; Carbo, Michiel; Consonni, Stefano; Jansen, Daniel

2011-01-01

Highlights: → We aim at defining the preferred IGCC design for dry feed gasifiers with CO 2 capture. → Multiple options of syngas cooling, humidification, and WGS are considered. → Plants are designed, modeled, numerically optimized and costs are carefully assessed. → Partial water quench has poor efficiency but low capital cost, then good performance. → Gas quench with the ECN staged WGS design has the best thermo-economic performance. -- Abstract: The Shell coal integrated gasification combined cycle (IGCC) based on the gas quench system is one of the most fuel flexible and energy efficient gasification processes because is dry feed and employs high temperature syngas coolers capable of rising high pressure steam. Indeed the efficiency of a Shell IGCC with the best available technologies is calculated to be 47-48%. However the system looses many percentage points of efficiency (up to 10) when introducing carbon capture. To overcome this penalty, two approaches have been proposed. In the first, the expensive syngas coolers are replaced by a 'partial water quench' where the raw syngas stream is cooled and humidified via direct injection of hot water. This design is less costly, but also less efficient. The second approach retains syngas coolers but instead employs novel water-gas shift (WGS) configurations that requires substantially less steam to obtain the same degree of CO conversion to CO 2 , and thus increases the overall plant efficiency. We simulate and optimize these novel configurations, provide a detailed thermodynamic and economic analysis and investigate how these innovations alter the plant's efficiency, cost and complexity.

The application of a coupled artificial neural network and fault tree analysis model to predict coal and gas outbursts

Energy Technology Data Exchange (ETDEWEB)

Ruilin, Zhang [School of Safety Science and Engineering, Henan Polytechnic University, Jiaozuo, Henan Province, 454003, PR (China); Lowndes, Ian S. [Process and Environmental Research Division, Faculty of Engineering, University of Nottingham, University Park, Nottingham, NG7 2RD (United Kingdom)

2010-11-01

This paper proposes the use of a coupled fault tree analysis (FTA) and artificial neural network (ANN) model to improve the prediction of the potential risk of coal and gas outburst events during the underground mining of thick and deep Chinese coal seams. The model developed has been used to investigate the gas emission characteristics and the geological conditions that exist within the Huaibei coal mining region, Anhui province, China. The coal seams in this region exhibit a high incidence of coal and gas outbursts. An analysis of the results obtained from an initial application of an FTA model, identified eight dominant model parameters related to the gas content or geological conditions of the coal seams, which characterize the potential risk of in situ coal and gas outbursts. The eight dominant model parameters identified by the FTA method were subsequently used as input variables to an ANN model. The results produced by the ANN model were used to develop a qualitative risk index to characterize the potential risk level of occurrence of coal and gas outburst events. Four different potential risk alarm levels were defined: SAFE, POTENTIAL, HIGH and STRONG. Solutions to the prediction model were obtained using a combination of quantitative and qualitative data including the gas content or gas pressure and the geological and geotechnical conditions of coal seams. The application of this combined solution method identified more explicit and accurate model relationships between the in situ geological conditions and the potential risk of coal and gas outbursts. An analysis of the model solutions concluded that the coupled FTA and ANN model may offer a reliable alternative method to forecast the potential risk of coal and gas outbursts. (author)

Full scale calcium bromide injection with subsequent mercury oxidation and removal within wet flue gas desulphurization system: Experience at a 700 MW coal-fired power facility

Science.gov (United States)

Berry, Mark Simpson

The Environmental Protection Agency promulgated the Mercury and Air Toxics Standards rule, which requires that existing power plants reduce mercury emissions to meet an emission rate of 1.2 lb/TBtu on a 30-day rolling average and that new plants meet a 0.0002 lb/GWHr emission rate. This translates to mercury removals greater than 90% for existing units and greater than 99% for new units. Current state-of-the-art technology for the control of mercury emissions uses activated carbon injected upstream of a fabric filter, a costly proposition. For example, a fabric filter, if not already available, would require a 200M capital investment for a 700 MW size unit. A lower-cost option involves the injection of activated carbon into an existing cold-side electrostatic precipitator. Both options would incur the cost of activated carbon, upwards of 3M per year. The combination of selective catalytic reduction (SCR) reactors and wet flue gas desulphurization (wet FGD) systems have demonstrated the ability to substantially reduce mercury emissions, especially at units that burn coals containing sufficient halogens. Halogens are necessary for transforming elemental mercury to oxidized mercury, which is water-soluble. Plants burning halogen-deficient coals such as Power River Basin (PRB) coals currently have no alternative but to install activated carbon-based approaches to control mercury emissions. This research consisted of investigating calcium bromide addition onto PRB coal as a method of increasing flue gas halogen concentration. The treated coal was combusted in a 700 MW boiler and the subsequent treated flue gas was introduced into a wet FGD. Short-term parametric and an 83-day longer-term tests were completed to determine the ability of calcium bromine to oxidize mercury and to study the removal of the mercury in a wet FGD. The research goal was to show that calcium bromine addition to PRB coal was a viable approach for meeting the Mercury and Air Toxics Standards rule

Improving air quality in large cities by substituting natural gas for coal in China: changing idea and incentive policy implications

International Nuclear Information System (INIS)

Mao Xianqiang; Guo Xiurui; Chang Yongguan; Peng Yingdeng

2005-01-01

Natural gas has long been used in China mainly as chemical raw material. With the increasing emphasis on urban air pollution prevention, the issue of natural gas substitution to coal has been raised in many large Chinese cities. This paper reviews the environmental-economic-technical rationality of dashing-for-gas in urban area, especially for civil use such as cooking and heating in China. Taking Beijing and Chongqing as study cases, a cost-benefit analysis of natural gas substitution is done and the ongoing economic and system barriers to natural gas penetration are analyzed. Indications of natural gas penetration incentive policy making are given finally

Improving air quality in large cities by substituting natural gas for coal in China: changing idea and incentive policy implications

International Nuclear Information System (INIS)

Xianqiang Mao; Yingdeng Peng

2005-01-01

Natural gas has long been used in China mainly as chemical raw material. With the increasing emphasis on urban air pollution prevention, the issue of natural gas substitution to coal has been raised in many large Chinese cities. This paper reviews the environmental - economic - technical rationality of dashing-for-gas in urban area, especially for civil use such as cooking and heating in China. Taking Beijing and Chongqing as study cases, a cost-benefit analysis of natural gas substitution is done and the ongoing economic and system barriers to natural gas penetration are analyzed. Indications of natural gas penetration incentive policy making are given finally. (author)

Hydrogen production from coal using a nuclear heat source

Science.gov (United States)

Quade, R. N.

1976-01-01

A strong candidate for hydrogen production in the intermediate time frame of 1985 to 1995 is a coal-based process using a high-temperature gas-cooled reactor (HTGR) as a heat source. Expected process efficiencies in the range of 60 to 70% are considerably higher than all other hydrogen production processes except steam reforming of a natural gas. The process involves the preparation of a coal liquid, hydrogasification of that liquid, and steam reforming of the resulting gaseous or light liquid product. A study showing process efficiency and cost of hydrogen vs nuclear reactor core outlet temperature has been completed, and shows diminishing returns at process temperatures above about 1500 F. A possible scenario combining the relatively abundant and low-cost Western coal deposits with the Gulf Coast hydrogen users is presented which provides high-energy density transportation utilizing coal liquids and uranium.

Understanding coal quality and its relationship to power plant performance and costs

Energy Technology Data Exchange (ETDEWEB)

Jennison, K.D.; Stallard, G.S. [Black & Veatch International, Overland Park, KS (United States)

1995-12-01

The availability of reliable, reasonably priced energy is a necessary cornerstone for established and emerging economies. In addition to addressing coal quality issues strictly at a plant level, it is now prudent to consider long-term performance and economics of particular fuel sources to be selected in the light of system economics and reliability. In order to evaluate coal quality issues in a more comprehensive manner, it is important to develop both an approach and a set of tools which can support the various phases of the planning/analysis processes. The processes must consider the following: (1) Cost/availability of other potential coal supplies, including {open_quotes}raw{close_quotes} domestic sources, {open_quotes}cleaned {close_quotes} domestic sources, and other internationally marketed coals. (2) Power plant performance issues as function of plant design and fuel properties. (3) System expansion plans, candidate technologies, and associated capital and operating costs. (4) Projected load demand, for system and for individual units within the system. (5) Legislative issues such as environmental pressures, power purchase agreements, etc. which could alter the solution. (6) Economics of potential plans/strategies based on overall cost-effectiveness of the utility system, not just individual units. (7) Anticipated unit configuration, including addition of environmental control equipment or other repowering options. The Coal Quality Impact Model (CQIM{trademark}) is a PC-based computer program capable of predicting coal-related cost and performance impacts at electric power generating sites. The CQIM was developed for EPRI by Black & Veatch and represents over a decade of effort geared toward developing an extensible state-of-the-art coal quality assessment tool. This paper will introduce CQIM, its capabilities, and its application to Eastern European coal quality assessment needs.

Coal Mining and Coal Seam Gas on Gomeroi country: Sacred lands, economic futures and shifting alliances

International Nuclear Information System (INIS)

Norman, Heidi

2016-01-01

North western NSW has seen a host of interest groups working in alliance opposing coal and coal seam gas mining. These groups - farmers, residents and environmentalists share concerns about the impact on the unique black soil and aquifer, of fossil fuel more broadly. While these shared alliances across class, gender and generations are emergent, Aboriginal citizens are uniquely placed in this contest over land, environment and resources. This paper sets out to show the historical and contemporary significance of the place of Aboriginal people in the debate over land use, arguing that, for the first time in history, Aboriginal worlds are central to community futures. In this space, new relationships are being forged and new discourse is required to comprehend the complex position Aboriginal citizens have as custodians of place and at the same time, the responsibility to provide for families and communities, otherwise excluded from the prevailing modern economy. With reference to the history of both relationship to land and land usage over Gomeroi country, and drawing on ethnographic along with archival research, this article seeks to contribute to a critical understanding of Aboriginal people's dealings in relation to their land, their cultural and economic interests with in an emerging regional coal economy, and in turn how they are redefining the context for energy resource extraction, and energy policy. - Highlights: • Aboriginal worlds are central to community futures in Australia. • Prospecting for coal and coal seam gas is forcing Aboriginal land holders into new relationships. • The nexus between the coal economy & Aboriginal self-determination is deeply contested. • New discourses are emerging to comprehend the custodianship of place in the context of mining.

Test and survey on a next generation coal liquefying catalyst. Coal molecule scientific test and survey as the base for commercializing the coal liquefying technology; Jisedai sekitan ekika shokubai shiken chosa. Sekitan ekika gijutsu shogyoka kiban to shite no sekitan bunshi kagaku shiken chosa

Energy Technology Data Exchange (ETDEWEB)

NONE

1998-03-01

The test and survey on a next generation coal liquefying catalyst present a new proposal to raise catalytic activity in coal liquefaction, and perform demonstration experiments in a laboratory scale to search for possibility of developing a new coal liquefying catalyst from various viewpoints. To explain, discussions were given on the catalyst to perform the followings: liquefaction under extremely mild conditions by using ultra strong acids not limited only to metals; ion exchange method and swell carrying method to raise catalyst dispersion very highly, enhance the catalytic activity, and reduce the amount of catalyst to be used; mechanism of producing catalyst activating species to further enhance the activity of iron catalysts; and pursuit of morphological change in the activating species. The coal molecule scientific test and survey as the base for commercializing the coal liquefying technology performed the studies on the following items: pretreatment of coal that can realize reduction of coal liquefaction cost; configuration of the liquefaction reaction, liquefying catalysts, hydrocarbon gas generating mechanism, status of catalysts after liquefaction reaction, and reduction in gas purification cost by using gas separating membranes. Future possibilities were further searched through frank and constructive opinion exchanges among the committee members. (NEDO)

Lack of oil and gas resources leads to concentration on coal and nuclear energy

Energy Technology Data Exchange (ETDEWEB)

1989-10-20

The Bulgarian energy sector is characterised by a marked shortage of domestic resources. The country has no oil to speak of, no gas, relatively little hydro potential compared with its neighbours, and the one resource it does have in fair abundance - coal - is of the poorest quality. This poverty of resources has led to an extraordinary dependence on the Soviet Union for supplies of every resource and for technology to utilise them. Most oil, all gas, some electricity and even significant quantities of coal are all imported from the USSR. There is little Bulgaria can do about its oil needs for the transport sector, but otherwise current policy is to concentrate development in the nuclear and coal sectors. One of the main thrusts of the energy policy is to continue expansion of coal, largely opencast lignite deposits, in order to feed thermal power stations and, when clean coal technology is developed, to use coal in CHP plants. The country uses a small amount of natural gas but no development is foreseen; instead district heating is considered a more efficient use of resources. 5 figs., 1 tab.

Gas production strategy of underground coal gasification based on multiple gas sources.

Science.gov (United States)

Tianhong, Duan; Zuotang, Wang; Limin, Zhou; Dongdong, Li

2014-01-01

To lower stability requirement of gas production in UCG (underground coal gasification), create better space and opportunities of development for UCG, an emerging sunrise industry, in its initial stage, and reduce the emission of blast furnace gas, converter gas, and coke oven gas, this paper, for the first time, puts forward a new mode of utilization of multiple gas sources mainly including ground gasifier gas, UCG gas, blast furnace gas, converter gas, and coke oven gas and the new mode was demonstrated by field tests. According to the field tests, the existing power generation technology can fully adapt to situation of high hydrogen, low calorific value, and gas output fluctuation in the gas production in UCG in multiple-gas-sources power generation; there are large fluctuations and air can serve as a gasifying agent; the gas production of UCG in the mode of both power and methanol based on multiple gas sources has a strict requirement for stability. It was demonstrated by the field tests that the fluctuations in gas production in UCG can be well monitored through a quality control chart method.

Development of coal gas production technology acceptable for fuel cells; Nenryo denchiyo sekitan gas seizo gijutsu ni kansuru kenkyu

Energy Technology Data Exchange (ETDEWEB)

Watanabe, T [Center for Coal Utilization, Japan, Tokyo (Japan); Kimura, N; Omata, K [Electric Power Development Co. Ltd., Tokyo (Japan)

1996-09-01

In utilizing coal for high-efficiency direct power generation using fuel cells, it is necessary that coal be fed into the fuel cells after having been made into ash-free gaseous fuel. Research and development works are being carried out with an objective to develop a coal gasification furnace most suitable for fuel cells and establish a system to refine coal up to the one that can be fed into fuel cells. Fiscal 1995 has conducted investigations on coal gasification technologies, air separation technologies, and gas refining technologies as the important element technologies, and a trial design on integrated coal gasification fuel cell (IGFC) systems. This paper reports from among the above items the result of the trial design on an IGFC system using molten carbonate fuel cells. The paper describes system comparison on paths of produced gases and anode waste gas, comparison on refining processes using a wet system and a dry system, and parameter studies on oxygen concentration in gasifying agents. It was made clear that the suitable furnace is an oxygen blown coal gasification furnace, and the power generation efficiency at the system terminal can be higher than 53%. 11 figs., 6 tabs.

Evaluating the gas content of coals and isolated maceral concentrates from the Paleocene Guasare Coalfield, Venezuela

International Nuclear Information System (INIS)

Berbesi, L.A.; Marquez, G.; Martinez, M.; Requena, A.

2009-01-01

This work presents the results from evaluating the gases sorbed by coal samples extracted from the Paleocene Guasare Coalfield (Marcelina Formation, northwestern Venezuela), as well as by their distinct maceral concentrates. The aim of this work has been to obtain an initial experimental main value of the gas content per unit weight of high volatile bituminous A coal samples from the open-pit Paso Diablo mine. An additional goal was to study differences in the CH 4 storage ability of the distinct maceral groups forming part of the coal matrix. Both the coal samples and the maceral concentrates were studied by thermogravimetric analysis (TGA) in order to determine the temperature to be used in subsequent experiments. On-line analyses of hydrocarbons (C 1 , C 2 , C 3 ) and CO 2 yielded gas concentrations, plus δ 13 C values. Thermogenic gas is prevalent in the Guasare coals with vitrinite reflectance (%R o ) values from 0.65% to 0.88%. The amount of gas retained in the coals and maceral concentrates was measured with a special device that allows determination of the volume of gas sorbed by a solid sample subjected to controlled thermal treatment. The average coalbed gas concentration obtained was 0.51 cm 3 /g. The following list of maceral concentrates shows the relative capacity for the volume of sorbed gas per unit weight: inertinite > low-density vitrinite > liptinite ∼ high-density vitrinite. It is concluded that the gas volumes retained in the distinct maceral concentrates are not controlled by porosity but rather by their microscopic morphology.

Nuclear power more profitable than coal if funded with low cost capital: A South-African case study

International Nuclear Information System (INIS)

Serfontein, Dawid E.

2014-01-01

This study summarizes and expands on economic simulation results from the author’s reviews of the South-African Government’s Draft Integrated Energy Plan (IEP) and Integrated Resource Plan Update 2013 (IRP Update). The Levellized Cost of Electricity (LCOE), as a function of the pre-tax Weighted Average Cost of Capital (WACC%) and the pre-tax % rate of return and the pre-tax nominal profit per unit power sold (R/kWh), as a function of the electricity selling price, are compared for a new Generation III nuclear plant and a new pulverized coal plant with Flue Gas Desulphurization (FGD), built in South Africa. All monetary amounts are expressed in constant real 2012 South African Rand (R), i.e. inflation has been removed. An exchange rate of R8.01/$ was assumed. Since the key economic features of HTRs and Generation III water-cooled nuclear plants are similar, e.g. high initial capital cost followed by low fuel and other variable costs and long plant lives, these results for Generation III nuclear plants are also applicable to HTRs. The results show that the LCOE for nuclear increases sharply with the pre-tax WACC%. For low WACC percentages, nuclear power is much cheaper than coal and vice versa. However the pre-tax nominal profit per unit nuclear power sold (R/kWh) greatly outperforms coal for all values of the electricity selling price, even if the nuclear overnight cost increases to the much maligned $7,000/kW-installed. Especially impressive is the result that nuclear already breaks even at R 0.30/kWh while coal will run at a loss until the price is increased to R 0.68/kWh. This result, that nuclear produces the most profitable power of all readily available sources in South Africa, implies the following power plant construction strategy: Supply the minimum expected new base-load with nuclear plants, augmented by peaking plants, such as hydro and gas turbine in order to balance the constant base-load power supply with the varying demand during different times

Numerical simulation of coupled binary gas-solid interaction during carbon dioxide sequestration in a coal bed

International Nuclear Information System (INIS)

Feng Qiyan; Zhou Lai; Chen Zhongwei; Liu Jishan

2008-01-01

Complicated coupled binary gas-solid interaction arises during carbon dioxide sequestration in a coal seam, which combines effects of CO 2 -CH 4 counter adsorption, CO 2 -CH 4 counter diffusion, binary gas flow and coal bed deformation. Through solving a set of coupled field governing equations, a novel full coupled Finite Element (FE) model was established by COMSOL Multiphysics. The new FE model was applied to the quantification of coal porous pressure, coal permeability, gas composition fraction and coal displacement when CO 2 was injected in a CH 4 saturated coal bed. Numerical results demonstrate that CH 4 is swept by the injected CO 2 accompanied by coal volumetric deformation. Compared to the single CH 4 in situ, CH 4 -CO 2 counter-diffusion induced coal swelling can make more compensation for coal shrinkage due to effective stress. Competing influences between the effective stress and the CH 4 -CO 2 counter-diffusion induced volume change governs the evolution of porous pressure and permeability, which is controlled by the porous pressure correspondingly. This achievement extends our ability to understand the coupled multi-physics of the CO 2 geological sequestration and CO 2 enhanced coal bed methane recovery under field conditions. (authors)

Slag processing system for direct coal-fired gas turbines

Science.gov (United States)

Pillsbury, Paul W.

1990-01-01

Direct coal-fired gas turbine systems and methods for their operation are provided by this invention. The gas turbine system includes a primary zone for burning coal in the presence of compressed air to produce hot combustion gases and debris, such as molten slag. The turbine system further includes a secondary combustion zone for the lean combustion of the hot combustion gases. The operation of the system is improved by the addition of a cyclone separator for removing debris from the hot combustion gases. The cyclone separator is disposed between the primary and secondary combustion zones and is in pressurized communication with these zones. In a novel aspect of the invention, the cyclone separator includes an integrally disposed impact separator for at least separating a portion of the molten slag from the hot combustion gases.

Enabling Technology for Monitoring & Predicting Gas Turbine Health & Performance in COAL IGCC Powerplants

Energy Technology Data Exchange (ETDEWEB)

Kenneth A. Yackly

2004-09-30

The ''Enabling & Information Technology To Increase RAM for Advanced Powerplants'' program, by DOE request, has been re-directed, de-scoped to two tasks, shortened to a 2-year period of performance, and refocused to develop, validate and accelerate the commercial use of enabling materials technologies and sensors for Coal IGCC powerplants. The new program has been re-titled as ''Enabling Technology for Monitoring & Predicting Gas Turbine Health & Performance in IGCC Powerplants'' to better match the new scope. This technical progress report summarizes the work accomplished in the reporting period April 1, 2004 to August 31, 2004 on the revised Re-Directed and De-Scoped program activity. The program Tasks are: Task 1--IGCC Environmental Impact on high Temperature Materials: This first materials task has been refocused to address Coal IGCC environmental impacts on high temperature materials use in gas turbines and remains in the program. This task will screen material performance and quantify the effects of high temperature erosion and corrosion of hot gas path materials in Coal IGCC applications. The materials of interest will include those in current service as well as advanced, high-performance alloys and coatings. Task 2--Material In-Service Health Monitoring: This second task develops and demonstrates new sensor technologies to determine the in-service health of advanced technology Coal IGCC powerplants, and remains in the program with a reduced scope. Its focus is now on only two critical sensor need areas for advanced Coal IGCC gas turbines: (1) Fuel Quality Sensor for detection of fuel impurities that could lead to rapid component degradation, and a Fuel Heating Value Sensor to rapidly determine the fuel heating value for more precise control of the gas turbine, and (2) Infra-Red Pyrometer to continuously measure the temperature of gas turbine buckets, nozzles, and combustor hardware.

Microbial desulfurization of coal

International Nuclear Information System (INIS)

Bos, P.; Boogerd, F.C.; Kuenen, J.G.

1992-01-01

In recent years, studies have been initiated to explore the possibilities of the use of biological systems in coal technology. This chapter discusses the principles behind the bioprocessing of coal, the advantages and disadvantages, and the economic feasibility of the process. For large-scale, coal-using, energy-producing plants, stack gas cleaning should be the treatment of choice. Biodesulfurization is preferable with industrial, small-scale, energy-producing plants. Treatment of the stack gases of these plants is not advisable because of high investment costs. Finally, it should be realized that biodesulfurization produces a waste stream that needs further treatment. 91 refs

Strategic considerations for clean coal R and D

International Nuclear Information System (INIS)

McMullan, J.T.; Williams, B.C.; McCahey, S.

2001-01-01

While present interest in coal-fired power generation is centred on the developing countries, with new natural-gas-fired power stations predominating in the developed world, in the long term coal will return to being the fuel of choice for power generation for much of the world. To minimise the global impact of coal use it is essential, therefore, that coal technologies are developed that are efficient, clean and economically attractive. Techno-economic analyses of the options for coal are presented together with a strategic overview of potential lines of development. The broad conclusions are that new coal plants will not be truly competitive with natural gas until the price of gas increases to about 3.3 EURO/GJ, compared with a coal price of 1.3 EURO/GJ. Present state-of-the-art pulverised coal-fired plant is close to its optimum techno-economic performance and further improvements depend on the development of cost-effective super-alloys. However, there are good opportunities to increase the efficiency of coal use to greater than 50% (LHV basis) using gasification-based power generation cycles. Unless credit is given for the much lower emissions provided by these cycles, the pulverised coal and pressurised fluidised bed combustion will remain the most economic options. (author)

Production of gasoline from coal or natural gas by the methanol-to-gasoline process

Energy Technology Data Exchange (ETDEWEB)

Heinritz-Adrian, M.; Brandl, A.; Zhoa, Xinjin; Tabak, S. [Uhde GmbH, Dortmund (Germany)

2007-07-01

After discussing the basis of the methanol-to-gas (MTG) process, the fixed bed and fluid bed versions are described. The Motunui and MTG complex near Montunui, New Zealand that methanol uses natural gas is briefly described. Shanxi Jincheng, Anthracite Coal Mining Co. is currently building its first coal-based MTG plant. 7 refs., 2 tabs.

Wettability determination by contact angle measurements: hvbB coal-water system with injection of synthetic flue gas and CO2.

Science.gov (United States)

Shojai Kaveh, Narjes; Rudolph, E Susanne J; Wolf, Karl-Heinz A A; Ashrafizadeh, Seyed Nezameddin

2011-12-01

Geological sequestration of pure carbon dioxide (CO(2)) in coal is one of the methods to sequester CO(2). In addition, injection of CO(2) or flue gas into coal enhances coal bed methane production (ECBM). The success of this combined process depends strongly on the wetting behavior of the coal, which is function of coal rank, ash content, heterogeneity of the coal surface, pressure, temperature and composition of the gas. The wetting behavior can be evaluated from the contact angle of a gas bubble, CO(2) or flue gas, on a coal surface. In this study, contact angles of a synthetic flue gas, i.e. a 80/20 (mol%) N(2)/CO(2) mixture, and pure CO(2) on a Warndt Luisenthal (WL) coal have been determined using a modified pendant drop cell in a pressure range from atmospheric to 16 MPa and a constant temperature of 318 K. It was found that the contact angles of flue gas on WL coal were generally smaller than those of CO(2). The contact angle of CO(2) changes from water-wet to gas-wet by increasing pressure above 8.5 MPa while the one for the flue gas changes from water-wet to intermediate-wet by increasing pressure above 10 MPa. Copyright © 2011 Elsevier Inc. All rights reserved.

Overall requirements for an advanced underground coal extraction system. [environment effects, miner health and safety, production cost, and coal conservation

Science.gov (United States)

Goldsmith, M.; Lavin, M. L.

1980-01-01

Underground mining systems suitable for coal seams expoitable in the year 2000 are examined with particular relevance to the resources of Central Appalachia. Requirements for such systems may be summarized as follows: (1) production cost; (2)miner safety; (3) miner health; (4) environmental impact; and (5) coal conservation. No significant trade offs between production cost and other performance indices were found.

Fuel Cells in the Coal Energy Industry

Directory of Open Access Journals (Sweden)

Kolat Peter

1998-09-01

Full Text Available In march 1998 at the conference „Coal Utilization & Fuel Systems“ in Clearwater, USA representatives of U.S. Department of Energy presented the vision 21 focused on the electricity generation from coal for 21st century. The goal is a powerplant with the ability to produce the electricity from coal with the efficiency approaching 60% (higher heating value and emission levels of one-tenth of today´s technologies, The CO2 capture and permanent sequestration at the cost of $15/ton of CO2, and a cost of electricity of 3 cents per kilowatt-hour. The goal is believed to be achievable by the first quarter of the next century. The vision 21 is presented with several possible concepts. One of them is based on coal gasification with following hydrogen separation. The obtained hydrogen is used as a fuel for the cogeneration unit with fuel cells. The remaining gas can be liquefied and utilised as a fuel in the automotive industry or further chemically processed. The concept has several important features. Firstly, a very clean low cost electricity production. Secondly, it is comprised of fuel processing section and power processing section. The two sections need not to be co-located. In the world of the deregulated electricity generation this offers a major advantage. The technologies of fuel processing section – coal gasification and hydrogen separation have been successfully developed in the last two decades. A specificity of the fuel processing section of this concept is to obtain hydrogen rich gas with very low concentrations of substances, as CO, which cause a poisoning of electrodes of fuel cells leading to the decreasing fuel cells efficiency. Fuel cells, specially highly efficient coal-gas SOFC and MCFC, are expected to be commercially available by 2020. The natural-gas MCFC and SOFC plants should enter the commercial marketplace by the year 2002.

Is coal a four letter word?

International Nuclear Information System (INIS)

Davies, G.

2004-01-01

Political promises about the future phasing out of coal-fired power plants were presented in this paper, as well as a demonstration of coal's importance for baseload. Ontario's other energy supply options were discussed and compared, including imported hydro, nuclear projects, natural gas and green initiatives. It was stated that closing coal plants might reduce emissions by 6 per cent, but at a cost of 2 billion dollars per year. The importance of recognizing air sheds was stated, as well as financial penalties along with worsening air quality. A map of Ontario's air shed covering much of eastern North America illustrated this point. A comparison of approaches in the United States was drawn, where coal is the fuel of choice for new supply, with 92 new coal fired plants announced, and many new gas plants being cancelled. A chart of markets for new coal power plant technology was presented, as well as environmental statistics of clean coal. Criteria for coal power plant performance are: air emissions; by-product utilization; water use and discharge; efficiency and reliability; and, capital and product cost. Various research programs in the US were also discussed, with new performance targets examined. Options for Canada were presented. It was concluded that financial penalties, combined with the fact that air pollution has no borders may lead to a reevaluation of coal plant closure. Suggestions for improving coal plants include: the development of a clean air strategy; new investments in new technology for emission reduction; establishing a North American agreement on clean air with meaningful targets. Additionally, it was also suggested that treaty undertakings should involve Canadian participation in US technology development efforts. tabs., figs

Low-Btu coal gasification in the United States: company topical. [Brick producers

Energy Technology Data Exchange (ETDEWEB)

Boesch, L.P.; Hylton, B.G.; Bhatt, C.S.

1983-07-01

Hazelton and other brick producers have proved the reliability of the commercial size Wellman-Galusha gasifier. For this energy intensive business, gas cost is the major portion of the product cost. Costs required Webster/Hazelton to go back to the old, reliable alternative energy of low Btu gasification when the natural gas supply started to be curtailed and prices escalated. Although anthracite coal prices have skyrocketed from $34/ton (1979) to over $71.50/ton (1981) because of high demand (local as well as export) and rising labor costs, the delivered natural gas cost, which reached $3.90 to 4.20/million Btu in the Hazelton area during 1981, has allowed the producer gas from the gasifier at Webster Brick to remain competitive. The low Btu gas cost (at the escalated coal price) is estimated to be $4/million Btu. In addition to producing gas that is cost competitive with natural gas at the Webster Brick Hazelton plant, Webster has the security of knowing that its gas supply will be constant. Improvements in brick business and projected deregulation of the natural gas price may yield additional, attractive cost benefits to Webster Brick through the use of low Btu gas from these gasifiers. Also, use of hot raw gas (that requires no tar or sulfur removal) keeps the overall process efficiency high. 25 references, 47 figures, 14 tables.

Prediction and control of rock burst of coal seam contacting gas in deep mining

Energy Technology Data Exchange (ETDEWEB)

En-yuan Wang; Xiao-fei Liu; En-lai Zhao; Zhen-tang Liu [China University of Mining and Technology, Xuzhou (China). School of Safety Engineering

2009-06-15

By analyzing the characteristics and the production mechanism of rock burst that goes with abnormal gas emission in deep coal seams, the essential method of eliminating abnormal gas emission by eliminating the occurrence of rock burst or depressing the magnitude of rock burst was considered. The No.237 working face in Nanshan coal mine was selected as the typical working face contacting gas in deep mining; aimed at this working face, a system of rock burst prediction and control for coal seam contacting gas in deep mining was established using the three-dimensional distinct element code software 3DEC. This system includes three parts: (1) regional prediction of rock burst hazard before mining; (2) local prediction of rock burst hazard during mining; and (3) rock burts control by an electromagnetic radiation method and specific drilling method. 8 refs., 4 figs., 1 tab.

Environmental costs resulting from the use of hard coal to electricity generation in Poland

Science.gov (United States)

Stala-Szlugaj, Katarzyna; Grudziński, Zbigniew

2017-10-01

In the world's fuel mix used for generating electricity, the most common fossil fuel is coal. In the EU, coal combustion and electricity generation entail the need to purchase emission allowances (EUA) whose purchase costs affect the costs of electricity generation significantly. The research described in the article shows how current market conditions shape the profitability of generating electricity from coal and how Clean Dark Spread (CDS) changes as a function of changes in energy and coal prices at the assumed levels of emission and prices of EUA allowances. The article compares the results of CDS calculations in two variants. Areas have been highlighted where prices of both coal and EUA allowances cause CDS to assume values at which the prices of generated electricity do not cover the costs of fuel (i) and CO2 emission allowances, cover all costs (ii), or constitute positive prices (iii), but still do not cover all fixed costs. With higher power plant efficiency, CO2 emissions are lower (0.722 t/MWh). The costs of purchasing fuel required to generate 1 MWh of electricity are also lower. In such case—even with relatively high prices of coal—a power plant can achieve profitability of electricity generation.

Environmental costs resulting from the use of hard coal to electricity generation in Poland

Directory of Open Access Journals (Sweden)

Stala-Szlugaj Katarzyna

2017-01-01

Full Text Available In the world's fuel mix used for generating electricity, the most common fossil fuel is coal. In the EU, coal combustion and electricity generation entail the need to purchase emission allowances (EUA whose purchase costs affect the costs of electricity generation significantly. The research described in the article shows how current market conditions shape the profitability of generating electricity from coal and how Clean Dark Spread (CDS changes as a function of changes in energy and coal prices at the assumed levels of emission and prices of EUA allowances. The article compares the results of CDS calculations in two variants. Areas have been highlighted where prices of both coal and EUA allowances cause CDS to assume values at which the prices of generated electricity do not cover the costs of fuel (i and CO2 emission allowances, cover all costs (ii, or constitute positive prices (iii, but still do not cover all fixed costs. With higher power plant efficiency, CO2 emissions are lower (0.722 t/MWh. The costs of purchasing fuel required to generate 1 MWh of electricity are also lower. In such case—even with relatively high prices of coal—a power plant can achieve profitability of electricity generation.

Fiscal 1999 report on basic research for promotion of joint implementation programs. Research on collection and utilization of coal mine methane gas in Russia (Kuznetsk coal field); Russia (Kuznetsk tanden) ni okeru tanko methane gas kaishu riyo chosa hokokusho

Energy Technology Data Exchange (ETDEWEB)

NONE

2000-03-01

The above-mentioned effort is to comply with the COP3 (Third Session of the Conference of the Parties to the United Nations Framework Convention on Climate Change) joint implementation clause. At this coal field, mining facilities are growing superannuated and obsolescent in the prolonged business depression, causing frequent occurrence of disasters such as gas explosions. The coal mine gas collection rate at the Kuznetsk coal field is as low as 17%, with concern for safety discouraging sufficient collection. Even the small amount of the collected gas is, in the absence of gas utilizing facilities, totally discharged into the air. For the mitigation of global warming, for mining safety, and for the establishment of a foundation for business, it is desired that coal mine methane gas collection/utilization facilities and related technologies be introduced into the coal field. Gas purging from the pits is incomplete, which is attributed to the lack of equipment capable of excavating proper-diameter bores longer than 100m for longwall mining. Ventilation also needs improvement. The research is under way on the premise that highly reliable intermediate range (300m) boring equipment and gas management technologies will be available. Collection of gas of a 30-35% concentration level at a collection rate of 40% is the target. (NEDO)

The economical production of alcohol fuels from coal-derived synthesis gas. Quarterly technical progress report Number 8, 1 July, 1993--30 September, 1993

Energy Technology Data Exchange (ETDEWEB)

1993-10-01

Task 1, the preparation of catalyst materials, is proceeding actively. At WVU, catalysts based on Mo are being prepared using a variety of approaches to alter the oxidation state and environment of the Mo. At UCC and P, copper-based zinc chromite spinel catalysts will be prepared and tested. The modeling of the alcohol-synthesis reaction in a membrane reactor is proceeding actively. Under standard conditions, pressure drop in the membrane reactor has been shown to be negligible. In Task 2, base case designs had previously been completed with a Texaco gasifier. Now, similar designs have been completed using the Shell gasifier. A comparison of the payback periods or production cost of these plants shows significant differences among the base cases. However, a natural gas only design, prepared for comparison purposes, gives a lower payback period or production cost. Since the alcohol synthesis portion of the above processes is the same, the best way to make coal-derived higher alcohols more attractive economically than natural gas-derived higher alcohols is by making coal-derived syngas less expensive than natural gas-derived syngas. The maximum economically feasible capacity for a higher alcohol plant from coal-derived syngas appears to be 32 MM bbl/yr. This is based on consideration of regional coal supply in the eastern US, coal transportation, and regional product demand. The benefits of economics of scale are illustrated for the base case designs. A value for higher alcohol blends has been determined by appropriate combination of RVP, octane number, and oxygen content, using MTBE as a reference. This analysis suggests that the high RVP of methanol in combination with its higher water solubility make higher alcohols more valuable than methanol.

The challenge for gas: get price-competitive with coal-fired electricity

International Nuclear Information System (INIS)

Gill, Len

1999-01-01

The challenge for the gas industry is to become price competitive with coal-fired electricity if it wants a larger share of the energy market. Returning to the issue of greater use of gas for electricity generation, the author points out that although electricity prices were rising they were still below the point where gas-fired electricity generation was viable. Copyright (1999) The Australian Gas Journal

Shell coal IGCCS with carbon capture. Conventional gas quench vs. innovative configurations

Energy Technology Data Exchange (ETDEWEB)

Martellia, E.; Consonni, S. [Politecnico di Milano, Via Scalabrini 76, Piacenza (Italy); Kreutz, T. [Princeton University, Guyot Hall, Room 129, Princeton, NJ (United States); Carbo, M.; Jansen, D. [Energy research Centre of the Netherlands ECN, P.O. Box 1, 1755 ZG, Petten (Netherlands)

2011-11-15

The Shell coal integrated gasification combined cycle (IGCC) based on the gas quench system is one of the most fuel flexible and energy efficient gasification processes because is dry feed and employs high temperature syngas coolers capable of rising high pressure steam. Indeed the efficiency of a Shell IGCC with the best available technologies is calculated to be 47-48%. However the system looses many percentage points of efficiency (up to 10) when introducing carbon capture. To overcome this penalty, two approaches have been proposed. In the first, the expensive syngas coolers are replaced by a 'partial water quench' where the raw syngas stream is cooled and humidified via direct injection of hot water. This design is less costly, but also less efficient. The second approach retains syngas coolers but instead employs novel water-gas shift (WGS) configurations that requires substantially less steam to obtain the same degree of CO conversion to CO2, and thus increases the overall plant efficiency. We simulate and optimize these novel configurations, provide a detailed thermodynamic and economic analysis and investigate how these innovations alter the plant's efficiency, cost and complexity.

Gas Production Strategy of Underground Coal Gasification Based on Multiple Gas Sources

Directory of Open Access Journals (Sweden)

Duan Tianhong

2014-01-01

Full Text Available To lower stability requirement of gas production in UCG (underground coal gasification, create better space and opportunities of development for UCG, an emerging sunrise industry, in its initial stage, and reduce the emission of blast furnace gas, converter gas, and coke oven gas, this paper, for the first time, puts forward a new mode of utilization of multiple gas sources mainly including ground gasifier gas, UCG gas, blast furnace gas, converter gas, and coke oven gas and the new mode was demonstrated by field tests. According to the field tests, the existing power generation technology can fully adapt to situation of high hydrogen, low calorific value, and gas output fluctuation in the gas production in UCG in multiple-gas-sources power generation; there are large fluctuations and air can serve as a gasifying agent; the gas production of UCG in the mode of both power and methanol based on multiple gas sources has a strict requirement for stability. It was demonstrated by the field tests that the fluctuations in gas production in UCG can be well monitored through a quality control chart method.

Development of the first coal seam gas exploration program in Indonesia: Reservoir properties of the Muaraenim Formation, south Sumatra

Energy Technology Data Exchange (ETDEWEB)

Sosrowidjojo, I.B. [R and D Centre for Oil and Gas Technology, LEMIGAS, Jakarta (Indonesia); Saghafi, A. [CSIRO Energy Technology, P O Box 330, Newcastle, NSW, 2300 (Australia)

2009-09-01

The Late Miocene Muaraenim Formation in southern Sumatra contains thick coal sequences, mostly of low rank ranging from lignite to sub-bituminous, and it is believed that these thick low rank coals are the most prospective for the production of coal seam gas (CSG), otherwise known as coalbed methane (CBM), in Indonesia. As part of a major CSG exploration project, gas exploration drilling operations are being undertaken in Rambutan Gasfields in the Muaraenim Formation to characterize the CSG potential of the coals. The first stage of the project, which is described here, was designed to examine the gas reservoir properties with a focus on coal gas storage capacity and compositional properties. Some five CSG exploration boreholes were drilled in the Rambutan Gasfield, south of Palembang. The exploration boreholes were drilled to depths of {proportional_to} 1000 m into the Muaraenim Formation. Five major coal seams were intersected by these holes between the depths of 450 and 1000 m. The petrography of coal samples collected from these seams showed that they are vitrinite rich, with vitrinite contents of more than 75% (on a mineral and moisture free basis). Gas contents of up to 5.8 m{sup 3}/t were measured for the coal samples. The gas desorbed from coal samples contain mainly methane (CH{sub 4}) ranging from 80 to 93% and carbon dioxide (CO{sub 2}) ranging from 6 to 19%. The composition of the gas released into the production borehole/well is, however, much richer in CH{sub 4} with about 94 to 98% CH{sub 4} and less than 5% CO{sub 2}. The initial results of drilling and reservoir characterization studies indicate suitable gas recovery parameters for three of the five coal seams with a total thickness of more than 30 m. (author)

Effects of coal storage in air on physical and chemical properties of coal and on gas adsorption

Science.gov (United States)

Mastalerz, Maria; Solano-Acosta, W.; Schimmelmann, A.; Drobniak, A.

2009-01-01

This paper investigates changes in the high-volatile bituminous Lower Block Coal Member from Indiana owing to moisture availability and oxidation in air at ambient pressure and temperature over storage time. Specifically, it investigates changes in chemistry, in surface area, and pore structure, as well as changes in methane and carbon dioxide adsorption capacities. Our results document that the methane adsorption capacity increased by 40%, whereas CO2 adsorption capacity increased by 18% during a 13-month time period. These changes in adsorption are accompanied by changes in chemistry and surface area of the coal. The observed changes in adsorption capacity indicate that special care must be taken when collecting samples and preserving coals until adsorption characteristics are measured in the laboratory. High-pressure isotherms from partially dried coal samples would likely cause overestimation of gas adsorption capacities, lead to a miscalculation of coal-bed methane prospects, and provide deceptively optimistic prognoses for recovery of coal-bed methane or capture of anthropogenic CO2. ?? 2009 Elsevier B.V. All rights reserved.

Method for increasing the calorific value of gas produced by the in situ combustion of coal

Science.gov (United States)

Shuck, Lowell Z.

1978-01-01

The present invention relates to the production of relatively high Btu gas by the in situ combustion of subterranean coal. The coal bed is penetrated with a horizontally-extending borehole and combustion is initiated in the coal bed contiguous to the borehole. The absolute pressure within the resulting combustion zone is then regulated at a desired value near the pore pressure within the coal bed so that selected quantities of water naturally present in the coal will flow into the combustion zone to effect a hydrogen and carbon monoxide-producing steam-carbon reaction with the hot carbon in the combustion zone for increasing the calorific value of the product gas.

Air extraction in gas turbines burning coal-derived gas

Energy Technology Data Exchange (ETDEWEB)

Yang, Tah-teh; Agrawal, A.K.; Kapat, J.S.

1993-11-01

In the first phase of this contracted research, a comprehensive investigation was performed. Principally, the effort was directed to identify the technical barriers which might exist in integrating the air-blown coal gasification process with a hot gas cleanup scheme and the state-of-the-art, US made, heavy-frame gas turbine. The guiding rule of the integration is to keep the compressor and the expander unchanged if possible. Because of the low-heat content of coal gas and of the need to accommodate air extraction, the combustor and perhaps, the flow region between the compressor exit and the expander inlet might need to be modified. In selecting a compressed air extraction scheme, one must consider how the scheme affects the air supply to the hot section of the turbine and the total pressure loss in the flow region. Air extraction must preserve effective cooling of the hot components, such as the transition pieces. It must also ensure proper air/fuel mixing in the combustor, hence the combustor exit pattern factor. The overall thermal efficiency of the power plant can be increased by minimizing the total pressure loss in the diffusers associated with the air extraction. Therefore, a study of airflow in the pre- and dump-diffusers with and without air extraction would provide information crucial to attaining high-thermal efficiency and to preventing hot spots. The research group at Clemson University suggested using a Griffith diffuser for the prediffuser and extracting air from the diffuser inlet. The present research establishes that the analytically identified problems in the impingement cooling flow are factual. This phase of the contracted research substantiates experimentally the advantage of using the Griffith diffuser with air extraction at the diffuser inlet.

Comparative assessment of severe accident risks in the coal, oil and natural gas chains

International Nuclear Information System (INIS)

Burgherr, Peter; Eckle, Petrissa; Hirschberg, Stefan

2012-01-01

This study compared severe accident risks of fossil energy chains (coal, oil and natural gas), based on the historical experience contained in the comprehensive database ENSAD. Considered risk indicators focused on human health impacts, i.e., fatality rates and maximum consequences were calculated for a broad range of country groups. Generally, expected fatality rates were lowest for natural gas, intermediate for oil and highest for coal. Concerning maximum consequences of a single accident, natural gas also performed best, followed by coal, whereas accidents in the oil chain can claim significantly more fatalities. In general, OECD and EU 27 ranked top, while non-OECD countries and China in the case of coal were worst. The consideration of numerous additional country groups enabled a more detailed differentiation within the main bounding groups. Furthermore, differences among country groups are distinctly decreasing from coal to oil and natural gas, both for fatality rates and maximum consequences. The use of import adjusted-fatality rates indicates that fatality risks in supply countries are an essential aspect to understand how specific risk reduction strategies may affect other components of energy security, and thus tradeoffs and compromises are necessary. Finally, the proposed fatality risk score for fossil chains (FRS F ) allows a comparison of the combined accident risk for the considered fossil energy chains across individual countries, which can be visualized using risk mapping.

Mathematical modelling of flue gas tempered flames produced from pulverised coal fired with oxygen

Energy Technology Data Exchange (ETDEWEB)

Breussin, A.; Weber, R.; Kamp, W.L. van de

1997-10-01

The combustion of pulverised coal in conventional utility boilers contributes significantly to global CO{sub 2} emissions. Because atmospheric air is used as the combustion medium, the exhaust gases of conventional pulverised coal fired utility boilers contain approximately 15 % CO{sub 2}. This relatively low concentration makes separating and recovering CO{sub 2} a very energy-intensive process. This process can be simplified if N{sub 2} is eliminated from the comburent before combustion by firing the pulverised coal with pure oxygen. However, this concept will result in very high flames temperatures. Flue gas recirculation can be used to moderate the flame temperature, whilst generating a flue gas with a CO{sub 2} concentration of 95 %. In this presentation, both experimental and modelling work will be described. The former deals with identifying the issues related to the combustion of pulverised coal in simulated turbine exhaust gas, particularly with respect to stability, burnout and pollutant emissions. The second part of this presentation describes mathematical modelling of type 2 as well as type 1 swirling pulverised coal flames. Future work will concentrate on high CO{sub 2} levels environments. (orig.)

Report for fiscal 1995 by Coal Gasification Committee; 1995 nendo sekitan gas ka iinkai hokokusho

Energy Technology Data Exchange (ETDEWEB)

NONE

1996-03-01

This is a summary primarily of the distributed material. As of December 14, 1995, the 200t/d pilot plant for power generation by entrained bed coal gasification records a total coal gasification operation time of 4,485 hours with an accumulated amount of power generation of 9,227MWh. A large combustor is tested, and it is found that combustion is stable under a 1/4 load with low NOx emissions. The combustor is sufficiently cooled with a small supply of air. Coal ash and coal, supplied in a constant state for an improved heat recovery efficiency in the development of hydrogen-from-coal technology, are heated to a temperature near their melting points. They are then allowed to impinge at a heat transfer plane simulating a gasifier heat recovery section, and a study is made of the mechanism of ash adhesion, molten or semi-molten, to the heat recovery section. The reduction of the heat transfer coefficient due to added grains is 30-50%, and the reduction is small when the heat transfer pipe surface velocity is high or when the carbon concentration in the grains is high. In another effort, utilization of coal-derived gas as town gas is studied. As for yields as indicated by the Curie gas pyrolyzer, the gas yield increases and liquid yield decreases when the reaction temperature is high. Using a small test unit, it is found that a rise in the hydrogen partial pressure increases the production of both gas and liquid. (NEDO)

Method of gas emission control for safe working of flat gassy coal seams

Science.gov (United States)

Vinogradov, E. A.; Yaroshenko, V. V.; Kislicyn, M. S.

2017-10-01

The main problems at intensive flat gassy coal seam longwall mining are considered. For example, mine Kotinskaja JSC “SUEK-Kuzbass” shows that when conducting the work on the gassy coal seams, methane emission control by means of ventilation, degassing and insulated drain of methane-air mixture is not effective and stable enough. It is not always possible to remove the coal production restrictions by the gas factor, which leads to financial losses because of incomplete using of longwall equipment and the reduction of the technical and economic indicators of mining. To solve the problems, the authors used a complex method that includes the compilation and analysis of the theory and practice of intensive flat gassy coal seam longwall mining. Based on the results of field and numerical researches, the effect of parameters of technological schemes on efficiency of methane emission control on longwall panels, the non-linear dependence of the permissible according to gas factor longwall productivity on parameters of technological schemes, ventilation and degassing during intensive mining flat gassy coal seams was established. The number of recommendations on the choice of the location and the size of the intermediate section of coal heading to control gassing in the mining extracted area, and guidelines for choosing the parameters of ventilation of extracted area with the help of two air supply entries and removal of isolated methane-air mixture are presented in the paper. The technological scheme, using intermediate entry for fresh air intake, ensuring effective management gassing and allowing one to refuse from drilling wells from the surface to the mined-out space for mining gas-bearing coal seams, was developed.

Method for enhancing the desulfurization of hot coal gas in a fluid-bed coal gasifier

Science.gov (United States)

Grindley, Thomas

1989-01-01

A process and apparatus for providing additional desulfurization of the hot gas produced in a fluid-bed coal gasifier, within the gasifier. A fluid-bed of iron oxide is located inside the gasifier above the gasification bed in a fluid-bed coal gasifier in which in-bed desulfurization by lime/limestone takes place. The product gases leave the gasification bed typically at 1600.degree. to 1800.degree. F. and are partially quenched with water to 1000.degree. to 1200.degree. F. before entering the iron oxide bed. The iron oxide bed provides additional desulfurization beyond that provided by the lime/limestone.

Medium Btu gas from coal: a possible solution to the U. S. energy crisis

Energy Technology Data Exchange (ETDEWEB)

Taffe, P

1978-03-03

The future of coal gasification in the US, and in particular the potential of the Winkler process, are discussed. The economics and the efficiency of the Winkler process are considered. It is believed that medium Btu gas from coal is a better solution to the US energy crisis than is SNG made from coal.

Coal fired steam generation for heavy oil recovery

International Nuclear Information System (INIS)

Firmin, K.

1992-01-01

In Alberta, some 21,000 m 3 /d of heavy oil and bitumen are produced by in-situ recovery methods involving steam injection. The steam generation requirement is met by standardized natural-gas-fired steam generators. While gas is in plentiful supply in Alberta and therefore competitively priced, significant gas price increases could occur in the future. A 1985 study investigating the alternatives to natural gas as a fuel for steam generation concluded that coal was the most economic alternative, as reserves of subbituminous coal are not only abundant in Alberta but also located relatively close to heavy oil and bitumen production areas. The environmental performance of coal is critical to its acceptance as an alternate fuel to natural gas, and proposed steam generator designs which could burn Alberta coal and control emissions satisfactorily are assessed. Considerations for ash removal, sulfur dioxide sorption, nitrogen oxides control, and particulate emission capture are also presented. A multi-stage slagging type of coal-fired combustor has been developed which is suitable for application with oilfield steam generators and is being commissioned for a demonstration project at the Cold Lake deposit. An economic study showed that the use of coal for steam generation in heavy oil in-situ projects in the Peace River and Cold Lake areas would be economic, compared to natural gas, at fuel price projections and design/cost premises for a project timing in the mid-1990s. 7 figs., 3 tabs

An evaluation of Substitute natural gas production from different coal gasification processes based on modeling

International Nuclear Information System (INIS)

Karellas, S.; Panopoulos, K.D.; Panousis, G.; Rigas, A.; Karl, J.; Kakaras, E.

2012-01-01

Coal and lignite will play a significant role in the future energy production. However, the technical options for the reduction of CO 2 emissions will define the extent of their share in the future energy mix. The production of synthetic or substitute natural gas (SNG) from solid fossil fuels seems to be a very attractive process: coal and lignite can be upgraded into a methane rich gas which can be transported and further used in high efficient power systems coupled with CO 2 sequestration technologies. The aim of this paper is to present a modeling analysis comparison between substitute natural gas production from coal by means of allothermal steam gasification and autothermal oxygen gasification. In order to produce SNG from syngas several unit operations are required such as syngas cooling, cleaning, potential compression and, of course, methanation reactors. Finally the gas which is produced has to be conditioned i.e. removal of unwanted species, such as CO 2 etc. The heat recovered from the overall process is utilized by a steam cycle, producing power. These processes were modeled with the computer software IPSEpro™. An energetic and exergetic analysis of the coal to SNG processes have been realized and compared. -- Highlights: ► The production of SNG from coal is examined. ► The components of the process were simulated for integrated autothermal or allothermal coal gasification to SNG. ► The energetic and exergetic evaluation of the two processes is presented.

CoalVal-A coal resource valuation program

Science.gov (United States)

Rohrbacher, Timothy J.; McIntosh, Gary E.

2010-01-01

CoalVal is a menu-driven Windows program that produces cost-of-mining analyses of mine-modeled coal resources. Geological modeling of the coal beds and some degree of mine planning, from basic prefeasibility to advanced, must already have been performed before this program can be used. United States Geological Survey mine planning is done from a very basic, prefeasibility standpoint, but the accuracy of CoalVal's output is a reflection of the accuracy of the data entered, both for mine costs and mine planning. The mining cost analysis is done by using mine cost models designed for the commonly employed, surface and underground mining methods utilized in the United States. CoalVal requires a Microsoft Windows? 98 or Windows? XP operating system and a minimum of 1 gigabyte of random access memory to perform operations. It will not operate on Microsoft Vista?, Windows? 7, or Macintosh? operating systems. The program will summarize the evaluation of an unlimited number of coal seams, haulage zones, tax entities, or other area delineations for a given coal property, coalfield, or basin. When the reader opens the CoalVal publication from the USGS website, options are provided to download the CoalVal publication manual and the CoalVal Program. The CoalVal report is divided into five specific areas relevant to the development and use of the CoalVal program: 1. Introduction to CoalVal Assumptions and Concepts. 2. Mine Model Assumption Details (appendix A). 3. CoalVal Project Tutorial (appendix B). 4. Program Description (appendix C). 5. Mine Model and Discounted Cash Flow Formulas (appendix D). The tutorial explains how to enter coal resource and quality data by mining method; program default values for production, operating, and cost variables; and ones own operating and cost variables into the program. Generated summary reports list the volume of resource in short tons available for mining, recoverable short tons by mining method; the seam or property being mined

NOx results from two combustors tested on medium BTU coal gas

Science.gov (United States)

Sherlock, T. P.; Carl, D. E.; Vermes, G.; Schwab, J.; Notardonato, J. J.

1982-01-01

The results of tests of two combustor configurations using coal gas from a 25 ton/day fluidized bed coal gasifier are reported. The trials were run with a ceramic-lined, staged rich/lean burner and an integral, all metal multiannular swirl burner (MASB) using a range of temperatures and pressures representative of industrial turbine inlet conditions. A lean mixture was examined at 104, 197, and 254 Btu/Scf, yielding NO(x) emissions of 5, 20, and 70 ppmv, respectively. The MASB was employed only with a gas rated at 220-270 Btu/Scf, producing 80 ppmv NO(x) at rated engine conditions. The results are concluded to be transferrable to current machines. Further tests on the effects of gas composition, the scaling of combustors to utility size, and the development of improved wall cooling techniques and variable geometry are indicated.

Coal gasification and the power production market

International Nuclear Information System (INIS)

Howington, K.; Flandermeyer, G.

1995-01-01

The US electric power production market is experiencing significant changes sparking interest in the current and future alternatives for power production. Coal gasification technology is being marketed to satisfy the needs of the volatile power production industry. Coal gasification is a promising power production process in which solid coal is burned to produce a synthesis gas (syn gas). The syn gas may be used to fuel combustion integrated into a facility producing electric power. Advantages of this technology include efficient power production, low flue gas emissions, flexible fuel utilization, broad capability for facility integration, useful process byproducts, and decreased waste disposal. The primary disadvantages are relatively high capital costs and lack of proven long-term operating experience. Developers of coal gasification intend to improve on these disadvantages and lop a strong position in the power generation market. This paper is a marketing analysis of the partial oxidation coal gasification processes emerging in the US in response to the market factors of the power production industry. A brief history of these processes is presented, including the results of recent projects exploring the feasibility of integrated gasification combined cycle (IGCC) as a power production alternative. The current power generation market factors are discussed, and the status of current projects is presented including projected performance

CO2 abatement policies in the power sector under an oligopolistic gas market

International Nuclear Information System (INIS)

Hecking, Harald

2014-01-01

The paper at hand examines the power system costs when a coal tax or a fixed bonus for renewables is combined with CO 2 emissions trading. It explicitly accounts for the interaction between the power and the gas market and identifies three cost effects: First, a tax and a subsidy both cause deviations from the cost-efficient power market equilibrium. Second, these policies also impact the power sector's gas demand function as well as the gas market equilibrium and therefore have a feedback effect on power generation quantities indirectly via the gas price. Thirdly, by altering gas prices, a tax or a subsidy also indirectly affects the total costs of gas purchase by the power sector. However, the direction of the change in the gas price, and therefore the overall effect on power system costs, remains ambiguous. In a numerical analysis of the European power and gas market, I find using a simulation model integrating both markets that a coal tax affects gas prices ambiguously whereas a fixed bonus for renewables decreases gas prices. Furthermore, a coal tax increases power system costs, whereas a fixed bonus can decrease these costs because of the negative effect on the gas price. Lastly, the more market power that gas suppliers have, the stronger the outlined effects will be.

Projected Costs of Generating Electricity

International Nuclear Information System (INIS)

Plante, J.

1998-01-01

Every 3 to 4 years, the NEA undertakes a study on projected costs of generating electricity in OECD countries. This started in 1983 and the last study (1997) has just be completed. All together 5 studies were performed, the first three dealing with nuclear and coal options, while the 1992 and 1997 included also the gas option. The goal of the study is to compare, country by country, generating costs of nuclear, coal-fired and gas-fired power plants that could be commissioned in the respondent countries by 2005-2010

The Efficiency Improvement by Combining HHO Gas, Coal and Oil in Boiler for Electricity Generation

Directory of Open Access Journals (Sweden)

Chia-Nan Wang

2017-02-01

Full Text Available Electricity is an essential energy that can benefit our daily lives. There are many sources available for electricity generation, such as coal, natural gas and nuclear. Among these sources, coal has been widely used in thermal power plants that account for about 41% of the worldwide electricity supply. However, these thermal power plants are also found to be a big pollution source to our environment. There is a need to explore alternative electricity sources and improve the efficiency of electricity generation. This research focuses on improving the efficiency of electricity generation through the use of hydrogen and oxygen mixture (HHO gas. In this research, experiments have been conducted to investigate the combined effects of HHO gas with other fuels, including coal and oil. The results show that the combinations of HHO with coal and oil can improve the efficiency of electricity generation while reducing the pollution to our environment.

Moderate temperature gas purification system: Application to high calorific coal-derived fuel

Energy Technology Data Exchange (ETDEWEB)

Kobayashi, M.; Shirai, H.; Nunokawa, M. [Central Research Institute of Electric Power Industry, Kanagawa (Japan)

2008-01-15

Simultaneous removal of dust, alkaline and alkaline-earth metals, halides and sulfur compounds is required to enlarge application of coal-derived gas to the high-temperature fuel cells and the fuel synthesis through chemical processing. Because high calorific fuel gas, such as oxygen-blown coal gas, has high carbon monoxide content, high-temperature (above 450{sup o}C) gas purification system is always subjected to the carbon deposition. We suggest moderate temperature (around 300{sup o}C) operation of the gas purification system to avoid the harmful disproportionation reaction and efficient removal of the various contaminants. Because the reaction rate is predominant to the performance of contaminant removal in the moderate temperature gas purification system, we evaluated the chemical removal processes; performance of the removal processes for halides and sulfur compounds was experimentally evaluated. The halide removal process with sodium aluminate sorbent had potential performance at around 300{sup o}C. The sulfur removal process with zinc ferrite sorbent was also applicable to the temperature range, though the reaction kinetics of the sorbent is essential to be approved.

Increasing coal-fired power generation efficiency to reduce electric cost and environmental emissions

International Nuclear Information System (INIS)

Torrens, I.M.; Stenzel, W.C.

1997-01-01

New generating capacity required globally between 1993 and 2010 is estimated to be around 1500 GW, of which some two-thirds will be outside the OECD, and some 40 % in the Asian non-OECD countries. Coal is likely to account for a substantial fraction of this new generation. Today's state-of-the-art supercritical coal-fired power plant has a conversion efficiency of some 42-45 %. The capital cost increase associated with the supercritical or ultra-supercritical pulverized coal power plant compared to a conventional subcritical plant is small to negligible. The increased efficiency associated with the supercritical plant leads to an actual reduction in the total cost of electricity generated in cents/kWh, relative to a conventional plant. Despite this, the power sector continues to build subcritical plants and has no near term plans to increase the efficiency of power plants in the projects it is developing. Advanced clean coal technologies such as integrated gasification combined cycle and pressurized fluidized bed combustion will be selected for independent power projects only in very specific circumstances. Advanced clean coal plants can be operated reliably and with superior performance, and specifically that their present estimated capital costs can be reduced substantially to a point where they are competitive with state-of-the-art pulverized coal technologies. (R.P.)

Potential Cost-Effective Opportunities for Methane Emission Abatement

Energy Technology Data Exchange (ETDEWEB)

Warner, Ethan [Joint Inst. for Strategic Energy Analysis, Golden, CO (United States); Steinberg, Daniel [Joint Inst. for Strategic Energy Analysis, Golden, CO (United States); Hodson, Elke [U.S. Department of Energy, Washington, DC (United States); Heath, Garvin [Joint Inst. for Strategic Energy Analysis, Golden, CO (United States)

2015-08-01

The energy sector was responsible for approximately 84% of carbon dioxide equivalent (CO₂e) greenhouse gas (GHG) emissions in the U.S. in 2012 (EPA 2014a). Methane is the second most important GHG, contributing 9% of total U.S. CO₂e emissions. A large portion of those methane emissions result from energy production and use; the natural gas, coal, and oil industries produce approximately 39% of anthropogenic methane emissions in the U.S. As a result, fossil-fuel systems have been consistently identified as high priority sectors to contribute to U.S. GHG reduction goals (White House 2015). Only two studies have recently attempted to quantify the abatement potential and cost associated with the breadth of opportunities to reduce GHG emissions within natural gas, oil, and coal supply chains in the United States, namely the U.S. Environmental Protection Agency (EPA) (2013a) and ICF (2014). EPA, in its 2013 analysis, estimated the marginal cost of abatement for non-CO₂ GHG emissions from the natural gas, oil, and coal supply chains for multiple regions globally, including the United States. Building on this work, ICF International (ICF) (2014) provided an update and re-analysis of the potential opportunities in U.S. natural gas and oil systems. In this report we synthesize these previously published estimates as well as incorporate additional data provided by ICF to provide a comprehensive national analysis of methane abatement opportunities and their associated costs across the natural gas, oil, and coal supply chains. Results are presented as a suite of marginal abatement cost curves (MACCs), which depict the total potential and cost of reducing emissions through different abatement measures. We report results by sector (natural gas, oil, and coal) and by supply chain segment - production, gathering and boosting, processing, transmission and storage, or distribution - to facilitate identification of which sectors and supply chain

Coal liquids -- Who needs them?

International Nuclear Information System (INIS)

Gray, D.; Tomlinson, G.

1995-01-01

The paper discusses the global energy demand situation as presented at the last World Energy Congress. The total energy demand was calculated for each country and projected to 2100. The paper then discusses the energy situation in the United States, especially the forecasted demand for crude oil and natural gas liquids. Imports will be needed to make up the shortfall in domestic production. The shortfall in conventional petroleum could be supplied by converting coal into liquid fuels. Currently the cost of high quality coal liquids is too high to compete with petroleum, but trends suggest that the price will be competitive in the year 2030 using current technology. Continuing research on coal liquefaction will reduce the price of coal liquids so that coal liquids could play a significant role sooner

Evaluation of catalytic combustion of actual coal-derived gas

Science.gov (United States)

Blanton, J. C.; Shisler, R. A.

1982-01-01

The combustion characteristics of a Pt-Pl catalytic reactor burning coal-derived, low-Btu gas were investigated. A large matrix of test conditions was explored involving variations in fuel/air inlet temperature and velocity, reactor pressure, and combustor exit temperature. Other data recorded included fuel gas composition, reactor temperatures, and exhaust emissions. Operating experience with the reactor was satisfactory. Combustion efficiencies were quite high (over 95 percent) over most of the operating range. Emissions of NOx were quite high (up to 500 ppm V and greater), owing to the high ammonia content of the fuel gas.

Energy Conversion Alternatives Study (ECAS), General Electric Phase 1. Volume 1: Executive summary. [using coal or coal derived fuels

Science.gov (United States)

Corman, J. C.

1976-01-01

A data base for the comparison of advanced energy conversion systems for utility applications using coal or coal-derived fuels was developed. Estimates of power plant performance (efficiency), capital cost, cost of electricity, natural resource requirements, and environmental intrusion characteristics were made for ten advanced conversion systems. Emphasis was on the energy conversion system in the context of a base loaded utility power plant. All power plant concepts were premised on meeting emission standard requirements. A steam power plant (3500 psig, 1000 F) with a conventional coal-burning furnace-boiler was analyzed as a basis for comparison. Combined cycle gas/steam turbine system results indicated competitive efficiency and a lower cost of electricity compared to the reference steam plant. The Open-Cycle MHD system results indicated the potential for significantly higher efficiency than the reference steam plant but with a higher cost of electricity.

Cofiring of rice straw and coal in a coal-fired utility boiler: thermodynamic analysis

Energy Technology Data Exchange (ETDEWEB)

Miyake, Raphael Guardini; Bazzo, Edson [Federal University of Santa Catarina (UFSC), Florianopolis, SC (Brazil). Dept. of Mechanical Engineering], Emails: miyake@labcet.ufsc.br, ebazzo@emc.ufsc.br; Bzuneck, Marcelo [Tractebel Energia, Capivari de Baixo, SC (Brazil)], E-mail: marcelob@tractebelenergia.com.br

2010-07-01

Cofiring combustion of biomass and coal is a near-term, low cost alternative for reduction fossil greenhouse gas emissions in coal fired power plants. Recent reviews identified over 288 applications in over 16 countries with promising results for different coal and biomass combinations. In Brazil, there is no previous experience of cofiring biomass and coal, resulting in new challenges to fuel handling and boiler operation. A first experience is now proposed into an existing coal power plant, using rice straw as biomass fuel. A thermodynamic model was developed in order to predict operating and emissions data, which should be used in cofiring system design. For 10% of biomass input, the total CO{sub 2} emission is expected to slightly increase. However, considering only the coal CO{sub 2} emission, it is expected to decrease in about 10%. Also, the corresponding SO{sub 2} emission decreases in about 8%. (author)

Post-test analysis of 20kW molten carbonate fuel cell stack operated on coal gas. Final report, August 1993--February 1996

Energy Technology Data Exchange (ETDEWEB)

NONE

1996-05-01

A 20kW carbonate fuel cell stack was operated with coal gas for the first time in the world. The stack was tested for a total of 4,000 hours, of which 3,900 hours of testing was conducted at the Louisiana Gasification Technology Incorporated, Plaquemine, Louisiana outdoor site. The operation was on either natural gas or coal gas and switched several times without any effects, demonstrating duel fuel capabilities. This test was conducted with 9142 kJ/m{sup 3} (245 Btu/cft) coal gas provided by a slipstream from Destec`s entrained flow, slagging, slurry-fed gasifier equipped with a cold gas cleanup subsystem. The stack generated up to 21 kW with this coal gas. Following completion of this test, the stack was brought to Energy Research Corporation (ERC) and a detailed post-test analysis was conducted to identify any effects of coal gas on cell components. This investigation has shown that the direct fuel cell (DFC) can be operated with properly cleaned and humidified coal-as, providing stable performance. The basic C direct fuel cell component materials are stable and display normal stability in presence of the coal gas. No effects of the coal-borne contaminants are apparent. Further cell testing at ERC 1 17, confirmed these findings.

Characteristic analysis of methane-gas generation by oxidizing heat of stored coal and hold ventilation control; Sekitan unpansen ni okeru sanka hatsunetsu ni yoru methane gas hassei to sonai kankyo seigyo ni tsuite

Energy Technology Data Exchange (ETDEWEB)

Fukuchi, N; Nakashima, T [Kyushu Univ., Fukuoka (Japan); Kudo, S

1999-12-31

A demand of coal shows the tendency in the increase worldwide, with this, the marine transportation of the coal gradually increases, and the collier has also enlarged. The traffic pattern of coal is mainly the bulk transportation. In this transportation system, by the oxidation exothermic reaction of the coal, methane gas is produced, simultaneously the coal quality such as coking property or heat quantity is decreased and sometimes spontaneous ignition is caused. Therefore, it is necessary to equip with a ventilator to control the concentration of methane gas and to avoid the self heating of the coal. In this study, the quantity of methane-gas produced by heating coal using an electric furnace was measured and the experiment to investigate the temperature dependency of the methane-gas generated from the coal was conducted. By using the result of the measurement, the quantity of methane-gas produced from the coal stored in the hold of a coal cargo was estimated. And, the mathematical analyses on the changing degree depend on the times of a temperature in the hold under navigation, a concentration of oxygen and a concentration of methane-gas, were conducted. 11 refs., 19 figs., 2 tabs.

Subsequent flue gas desulfurization of coal-fired power plant units

International Nuclear Information System (INIS)

Willibal, U.; Braun, Gy.

1998-01-01

The presently operating coal-fired power plant in Hungary do not satisfy the pollution criteria prescribed by the European Union norms. The main polluting agent is the sulfur dioxide emitted by some of the power plants in Hungary in quantities over the limit standards. The power plant units that are in good operating state could be made competitive by using subsequent desulfurization measures. Various flue gas desulfurization technologies are presented through examples that can be applied to existing coal-fired power plants. (R.P.)

Fiscal 1994 entrusted task report. Surveys of advanced natural gas development and efficient utilization (Survey of coal hydrogasification technology development); 1994 nendo tennen gas kodo kaihatsu yuko riyo chosa tou itaku gyomu hokokusho. Sekitan suiten gaska gijutsu kaihatsu chosa

Energy Technology Data Exchange (ETDEWEB)

NONE

1995-03-01

For the establishment of a practical process for substitute natural gas (SNG) production, technological and economical assessments were made, and tasks to discharge for the development were discussed. In this fiscal year, the results of surveys conducted in the past five-year period were compiled, and studies were made to prepare for a smooth transition to the element research stage. Findings obtained are described below. SNG producing technologies need to be developed, with the demand for SNG increasing sharply, to further stabilize the base for SNG supply; coal which is abundantly available should be used as the material for SNG; and coal hydrogasification, among various methods for producing SNG from coal, is the most suitable in view of efficiency and cost performance. It was also found after a prolonged study for the improvement of efficiency and cost performance that probabilities were high that the yield of BTX (benzene, toluene, xylene) would increase and cost performance would improve. Besides, a basic plan and an element technology research plan were prepared for the development of the ARCH (advanced rapid coal hydrogasification) process. (NEDO)

Pd/activated carbon sorbents for mid-temperature capture of mercury from coal-derived fuel gas.

Science.gov (United States)

Li, Dekui; Han, Jieru; Han, Lina; Wang, Jiancheng; Chang, Liping

2014-07-01

Higher concentrations of Hg can be emitted from coal pyrolysis or gasification than from coal combustion, especially elemental Hg. Highly efficient Hg removal technology from coal-derived fuel gas is thus of great importance. Based on the very excellent Hg removal ability of Pd and the high adsorption abilities of activated carbon (AC) for H₂S and Hg, a series of Pd/AC sorbents was prepared by using pore volume impregnation, and their performance in capturing Hg and H₂S from coal-derived fuel gas was investigated using a laboratory-scale fixed-bed reactor. The effects of loading amount, reaction temperature and reaction atmosphere on Hg removal from coal-derived fuel gas were studied. The sorbents were characterized by N₂ adsorption, X-ray diffraction (XRD) and X-ray photoelectron spectroscopy (XPS). The results indicated that the efficiency of Hg removal increased with the increasing of Pd loading amount, but the effective utilization rate of the active component Pd decreased significantly at the same time. High temperature had a negative influence on the Hg removal. The efficiency of Hg removal in the N₂-H₂S-H₂-CO-Hg atmosphere (simulated coal gas) was higher than that in N₂-H₂S-Hg and N₂-Hg atmospheres, which showed that H₂ and CO, with their reducing capacity, could benefit promote the removal of Hg. The XPS results suggested that there were two different ways of capturing Hg over sorbents in N₂-H₂S-Hg and N₂-Hg atmospheres. Copyright © 2014. Published by Elsevier B.V.

Development of standardized air-blown coal gasifier/gas turbine concepts for future electric power systems

Energy Technology Data Exchange (ETDEWEB)

1990-07-01

CRS Sirrine (CRSS) is evaluating a novel IGCC process in which gases exiting the gasifier are burned in a gas turbine combustion system. The turbine exhaust gas is used to generate additional power in a conventional steam generator. This results in a significant increase in efficiency. However, the IGCC process requires development of novel approaches to control SO{sub 2} and NO{sub x} emissions and alkali vapors which can damage downstream turbine components. Ammonia is produced from the reaction of coal-bound nitrogen with steam in the reducing zone of any fixed bed coal gasifier. This ammonia can be partially oxidized to NO{sub x} when the product gas is oxidized in a gas turbine combustor. Alkali metals vaporize in the high-temperature combustion zone of the gasifier and laser condense on the surface of small char or ash particles or on cooled metal surfaces. It these alkali-coated materials reach the gas turbine combustor, the alkali will revaporize condense on turbine blades and cause rapid high temperature corrosion. Efficiency reduction will result. PSI Technology Company (PSIT) was contracted by CRSS to evaluate and recommend solutions for NO{sub x} emissions and for alkali metals deposition. Various methods for NO{sub x} emission control and the potential process and economic impacts were evaluated. This included estimates of process performance, heat and mass balances around the combustion and heat transfer units and a preliminary economic evaluation. The potential for alkali metal vaporization and condensation at various points in the system was also estimated. Several control processes and evaluated, including an order of magnitude cost for the control process.

Economic effects of western Federal land-use restrictions on U.S. coal markets

Science.gov (United States)

Watson, William Downing; Medlin, A.L.; Krohn, K.K.; Brookshire, D.S.; Bernknopf, R.L.

1991-01-01

Current regulations on land use in the Western United States affect access to surface minable coal resources. This U.S. Geological Survey study analyzes the long-term effects of Federal land-use restrictions on the national cost of meeting future coal demands. The analysis covers 45 years. The U.S. Bureau of Land Management has determined the environmental, aesthetic, and economic values of western Federal coal lands and has set aside certain areas from surface coal mining to protect other valued land uses, including agricultural, environmental, and aesthetic uses. Although there are benefits to preserving natural areas and to developing areas for other land uses, these restrictions produce long-term national and regional costs that have not been estimated previously. The Dynamic Coal Allocation Model integrates coal supply (coal resource tonnage and coal quality by mining cost for 60 coal supply regions) with coal demand (in 243 regions) for the entire United States. The model makes it possible to evaluate the regional economic impacts of coal supply restrictions wherever they might occur in the national coal market. The main factors that the economic methodology considers are (1) coal mining costs, (2) coal transportation costs, (3) coal flue gas desulfurization costs, (4) coal demand, (5) regulations to control sulfur dioxide discharges, and (6) specific reductions in coal availability occurring as a result of land-use restrictions. The modeling system combines these economic factors with coal deposit quantity and quality information--which is derived from the U.S. Geological Survey's National Coal Resources Data System and the U.S. Department of Energy's Demonstrated Reserve Base--to determine a balance between supply and demand so that coal is delivered at minimum cost.

CATALYTIC GASIFICATION OF COAL USING EUTECTIC SALT MIXTURES

Energy Technology Data Exchange (ETDEWEB)

Dr. Yaw D. Yeboah; Dr. Yong Xu; Dr. Atul Sheth; Dr. Pradeep Agrawal

2001-12-01

The Gas Research Institute (GRI) estimates that by the year 2010, 40% or more of U.S. gas supply will be provided by supplements including substitute natural gas (SNG) from coal. These supplements must be cost competitive with other energy sources. The first generation technologies for coal gasification e.g. the Lurgi Pressure Gasification Process and the relatively newer technologies e.g. the KBW (Westinghouse) Ash Agglomerating Fluidized-Bed, U-Gas Ash Agglomerating Fluidized-Bed, British Gas Corporation/Lurgi Slagging Gasifier, Texaco Moving-Bed Gasifier, and Dow and Shell Gasification Processes, have several disadvantages. These disadvantages include high severities of gasification conditions, low methane production, high oxygen consumption, inability to handle caking coals, and unattractive economics. Another problem encountered in catalytic coal gasification is deactivation of hydroxide forms of alkali and alkaline earth metal catalysts by oxides of carbon (CO{sub x}). To seek solutions to these problems, a team consisting of Clark Atlanta University (CAU, a Historically Black College and University, HBCU), the University of Tennessee Space Institute (UTSI) and Georgia Institute of Technology (Georgia Tech) proposed to identify suitable low melting eutectic salt mixtures for improved coal gasification. The research objectives of this project were to: Identify appropriate eutectic salt mixture catalysts for coal gasification; Assess agglomeration tendency of catalyzed coal; Evaluate various catalyst impregnation techniques to improve initial catalyst dispersion; Determine catalyst dispersion at high carbon conversion levels; Evaluate effects of major process variables (such as temperature, system pressure, etc.) on coal gasification; Evaluate the recovery, regeneration and recycle of the spent catalysts; and Conduct an analysis and modeling of the gasification process to provide better understanding of the fundamental mechanisms and kinetics of the process.

Cost-Effectiveness of Emission Reduction for the Indonesian Coal-Fired Power Plants

NARCIS (Netherlands)

Handayani, Kamia; Krozer, Yoram

2014-01-01

This paper presents the result of research on the cost-effectiveness of emission reduction in the selected coal-fired power plants (CFPPs) in Indonesia. The background of this research is the trend of more stringent environmental regulation regarding air emission from coal-fired power plants (CFPPs)

Gas emissions, minerals, and tars associated with three coal fires, Powder River Basin, USA.

Science.gov (United States)

Engle, Mark A; Radke, Lawrence F; Heffern, Edward L; O'Keefe, Jennifer M K; Hower, James C; Smeltzer, Charles D; Hower, Judith M; Olea, Ricardo A; Eatwell, Robert J; Blake, Donald R; Emsbo-Mattingly, Stephen D; Stout, Scott A; Queen, Gerald; Aggen, Kerry L; Kolker, Allan; Prakash, Anupma; Henke, Kevin R; Stracher, Glenn B; Schroeder, Paul A; Román-Colón, Yomayra; ter Schure, Arnout

2012-03-15

Ground-based surveys of three coal fires and airborne surveys of two of the fires were conducted near Sheridan, Wyoming. The fires occur in natural outcrops and in abandoned mines, all containing Paleocene-age subbituminous coals. Diffuse (carbon dioxide (CO(2)) only) and vent (CO(2), carbon monoxide (CO), methane, hydrogen sulfide (H(2)S), and elemental mercury) emission estimates were made for each of the fires. Additionally, gas samples were collected for volatile organic compound (VOC) analysis and showed a large range in variation between vents. The fires produce locally dangerous levels of CO, CO(2), H(2)S, and benzene, among other gases. At one fire in an abandoned coal mine, trends in gas and tar composition followed a change in topography. Total CO(2) fluxes for the fires from airborne, ground-based, and rate of fire advancement estimates ranged from 0.9 to 780mg/s/m(2) and are comparable to other coal fires worldwide. Samples of tar and coal-fire minerals collected from the mouth of vents provided insight into the behavior and formation of the coal fires. Published by Elsevier B.V.

Cracking oils, etc. , glycerine, oil and coal gas

Energy Technology Data Exchange (ETDEWEB)

Mann, W

1919-02-06

In the cracking of hydrocarbon oils, the thermal decomposition of fats to obtain glycerine, the production of oil and coal gas, and the destructive distillation of coal, peat, shale, etc., the lower molecular weight products are separated, while the higher molecular weight products are separated, while the higher molecular weight products and undecomposed substances are retained for further exposure to the decomposition conditions, by interposing one or more porous septa between the decomposition chamber and the condenser or receiver. The decomposition conditions may be maintained up to the porous septum; but it is preferable to place the porous septum in a separate chamber inside or outside the decomposition vessel; and a plurality of decomposition chambers may be used in series or parallel.

Nuclear and coal-fired power plant capital costs 1978 -June 1981

International Nuclear Information System (INIS)

Harbour, R.T.

1981-07-01

This bibliography covers 16 papers dealing with the economics of power generation - mainly comparisons between the capital costs of nuclear and coal fired plants. Some of the papers additionally discuss fuel, operating and maintenance costs, and performance. (U.K.)

Structural comparison of hazardous and non-hazardous coals based on gas sorption experiments

Energy Technology Data Exchange (ETDEWEB)

Lakatos, J.; Toth, J. [Research Lab. for Mining Chemistry, Hungarian Academy of Sciences, Miskolc-Egyetemvaros (Hungary); Radnai-Gyoengyoes, Z. [Geopard Ltd., Pecs (Hungary); Bokanyi, L. [Miskolc Univ., Miskolc-Egyetemvaros (Hungary). Dept. of Process Engineering

1997-12-31

Comparison of carbon-dioxide and propane sorption at ambient temperature was used for characterising the difference of the structure of hazardous and non hazardous coals. However, hazardous coals were found more microporous or contain more closed pores than non hazardous ones, this difference couldn`t have been enlarged and attributed to one petrographic component by producing the density fractions. Gas sorption isobars (nitrogen, methane, ethane) are proposed to make a distinction between fine pore structure of coals. (orig.)

FIELD TEST PROGRAM TO DEVELOP COMPREHENSIVE DESIGN, OPERATING AND COST DATA FOR MERCURY CONTROL SYSTEMS ON NON-SCRUBBED COAL-FIRED BOILERS

International Nuclear Information System (INIS)

C. Jean Bustard

2001-01-01

With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Mercury is known to have toxic effects on the nervous system of humans and wildlife. Although it exists only in trace amounts in coal, mercury is released when coal burns and can accumulate on land and in water. In water, bacteria transform the metal into methylmercury, the most hazardous form of the metal. Methylmercury can collect in fish and marine mammals in concentrations hundreds of thousands times higher than the levels in surrounding waters. One of the goals of DOE is to develop technologies by 2005 that will be capable of cutting mercury emissions 50 to 70 percent at well under one-half of today's costs. ADA Environmental Solutions (ADA-ES) is managing a project to test mercury control technologies at full scale at four different power plants from 2000 to 2003. The ADA-ES project is focused on those power plants that are not equipped with wet flue gas desulfurization systems. ADA-ES will develop a portable system that will be moved to four different utility power plants for field testing. Each of the plants is equipped with either electrostatic precipitators or fabric filters to remove solid particles from the plant's flue gas. ADA-ES's technology will inject a dry sorbent, such as fly ash or activated carbon, that removes the mercury and makes it more susceptible to capture by the particulate control devices. A fine water mist may be sprayed into the flue gas to cool its temperature to the range where the dry sorbent is most effective. PG and E National Energy Group is providing two test sites that fire bituminous coals and are both equipped with electrostatic precipitators and carbon/ash separation systems. Wisconsin Electric Power Company is providing a third test site that burns Powder River Basin (PRB

FIELD TEST PROGRAM TO DEVELOP COMPREHENSIVE DESIGN, OPERATING AND COST DATA FOR MERCURY CONTROL SYSTEMS ON NON-SCRUBBED COAL-FIRED BOILERS

International Nuclear Information System (INIS)

C. Jean Bustard

2002-01-01

With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Mercury is known to have toxic effects on the nervous system of humans and wildlife. Although it exists only in trace amounts in coal, mercury is released when coal burns and can accumulate on land and in water. In water, bacteria transform the metal into methylmercury, the most hazardous form of the metal. Methylmercury can collect in fish and marine mammals in concentrations hundreds of thousands times higher than the levels in surrounding waters. One of the goals of DOE is to develop technologies by 2005 that will be capable of cutting mercury emissions 50 to 70 percent at well under one-half of today's costs. ADA Environmental Solutions (ADA-ES) is managing a project to test mercury control technologies at full scale at four different power plants from 2000-2003. The ADA-ES project is focused on those power plants that are not equipped with wet flue gas desulfurization systems. ADA-ES will develop a portable system that will be moved to four different utility power plants for field testing. Each of the plants is equipped with either electrostatic precipitators or fabric filters to remove solid particles from the plant's flue gas. ADA-ES's technology will inject a dry sorbent, such as fly ash or activated carbon, that removes the mercury and makes it more susceptible to capture by the particulate control devices. A fine water mist may be sprayed into the flue gas to cool its temperature to the range where the dry sorbent is most effective. PG and E National Energy Group is providing two test sites that fire bituminous coals and are both equipped with electrostatic precipitators and carbon/ash separation systems. Wisconsin Electric Power Company is providing a third test site that burns Powder River Basin (PRB

FIELD TEST PROGRAM TO DEVELOP COMPREHENSIVE DESIGN, OPERATING AND COST DATA FOR MERCURY CONTROL SYSTEMS ON NON-SCRUBBED COAL-FIRED BOILERS

International Nuclear Information System (INIS)

C. Jean Bustard

2001-01-01

With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Mercury is known to have toxic effects on the nervous system of humans and wildlife. Although it exists only in trace amounts in coal, mercury is released when coal burns and can accumulate on land and in water. In water, bacteria transform the metal into methylmercury, the most hazardous form of the metal. Methylmercury can collect in fish and marine mammals in concentrations hundreds of thousands times higher than the levels in surrounding waters. One of the goals of DOE is to develop technologies by 2005 that will be capable of cutting mercury emissions 50 to 70 percent at well under one-half of today's costs. ADA Environmental Solutions (ADA-ES) is managing a project to test mercury control technologies at full scale at four different power plants from 2000-2003. The ADA-ES project is focused on those power plants that are not equipped with wet flue gas desulfurization systems. ADA-ES will develop a portable system that will be moved to four different utility power plants for field testing. Each of the plants is equipped with either electrostatic precipitators or fabric filters to remove solid particles from the plant's flue gas. ADA-ES's technology will inject a dry sorbent, such as fly ash or activated carbon, that removes the mercury and makes it more susceptible to capture by the particulate control devices. A fine water mist may be sprayed into the flue gas to cool its temperature to the range where the dry sorbent is most effective. PG and E National Energy Group is providing two test sites that fire bituminous coals and are both equipped with electrostatic precipitators and carbon/ash separation systems. Wisconsin Electric Power Company is providing a third test site that burns Powder River Basin coal

FIELD TEST PROGRAM TO DEVELOP COMPREHENSIVE DESIGN, OPERATING AND COST DATA FOR MERCURY CONTROL SYSTEMS ON NON-SCRUBBED COAL-FIRED BOILERS

International Nuclear Information System (INIS)

C. Jean Bustard

2001-01-01

With the Nation's coal-burning utilities facing the possibility of tighter controls on mercury pollutants, the U.S. Department of Energy is funding projects that could offer power plant operators better ways to reduce these emissions at much lower costs. Mercury is known to have toxic effects on the nervous system of humans and wildlife. Although it exists only in trace amounts in coal, mercury is released when coal burns and can accumulate on land and in water. In water, bacteria transform the metal into methylmercury, the most hazardous form of the metal. Methylmercury can collect in fish and marine mammals in concentrations hundreds of thousands times higher than the levels in surrounding waters. One of the goals of DOE is to develop technologies by 2005 that will be capable of cutting mercury emissions 50 to 70 percent at well under one-half of today's costs. ADA Environmental Solutions (ADA-ES) is managing a project to test mercury control technologies at full scale at four different power plants from 2000-2003. The ADA-ES project is focused on those power plants that are not equipped with wet flue gas desulfurization systems. ADA-ES will develop a portable system that will be moved to four different utility power plants for field testing. Each of the plants is equipped with either electrostatic precipitators or fabric filters to remove solid particles from the plant's flue gas. ADA-ES's technology will inject a dry sorbent, such as fly ash or activated carbon, that removes the mercury and makes it more susceptible to capture by the particulate control devices. A fine water mist may be sprayed into the flue gas to cool its temperature to the range where the dry sorbent is most effective. PG and E National Energy Group is providing two test sites that fire bituminous coals and are both equipped with electrostatic precipitators and carbon/ash separation systems. Wisconsin Electric Power Company is providing a third test site that burns Powder River Basin (PRB

Gas cleaning and hydrogen sulfide removal for COREX coal gas by sorption enhanced catalytic oxidation over recyclable activated carbon desulfurizer.

Science.gov (United States)

Sun, Tonghua; Shen, Yafei; Jia, Jinping

2014-02-18

This paper proposes a novel self-developed JTS-01 desulfurizer and JZC-80 alkaline adsorbent for H2S removal and gas cleaning of the COREX coal gas in small-scale and commercial desulfurizing devices. JTS-01 desulfurizer was loaded with metal oxide (i.e., ferric oxides) catalysts on the surface of activated carbons (AC), and the catalyst capacity was improved dramatically by means of ultrasonically assisted impregnation. Consequently, the sulfur saturation capacity and sulfur capacity breakthrough increased by 30.3% and 27.9%, respectively. The whole desulfurizing process combined selective adsorption with catalytic oxidation. Moreover, JZC-80 adsorbent can effectively remove impurities such as HCl, HF, HCN, and ash in the COREX coal gas, stabilizing the system pressure drop. The JTS-01 desulfurizer and JZC-80 adsorbent have been successfully applied for the COREX coal gas cleaning in the commercial plant at Baosteel, Shanghai. The sulfur capacity of JTS-01 desulfurizer can reach more than 50% in industrial applications. Compared with the conventional dry desulfurization process, the modified AC desulfurizers have more merit, especially in terms of the JTS-01 desulfurizer with higher sulfur capacity and low pressure drop. Thus, this sorption enhanced catalytic desulfurization has promising prospects for H2S removal and other gas cleaning.

Study of gas holdup and pressure characteristics in a column flotation cell using coal

Energy Technology Data Exchange (ETDEWEB)

Shukla, S.C.; Kundu, G.; Mukherjee, D. [Indian Institute of Technology, Kharagpur (India). Dept. of Chemical Engineering

2010-07-15

Present work has been carried out to observe the effect of process variables (gas flow rate, feed flow rate, solid concentration and frother concentration) on gas holdup and pressure characteristics in flotation column using coal. Gas holdup has been estimated using phase separation method while piezometers have been used to obtain column's axial pressure profile. It was observed that gas holdup in collection zone was affected by both air as well as feed flow rates. Up to 6% change in gas holdup may occur when the feed flow rate changes from 1-2 cm/s. It was also observed that addition of coal decreased the gas holdup while addition of methyl isobutyl carbinol (MIBC) had opposite effect. Almost linear variation in columns axial pressure characteristics has been observed with gas flow rate. An empirical relationship between gas holdup in the flotation column with column's axial pressure difference was developed.

Gas migration from closed coal mines to the surface. Risk assessment methodology and prevention means

International Nuclear Information System (INIS)

Pokryszka, Z.; Tauziede, Ch.; Lagny, C.; Guise, Y.; Gobillot, R.; Planchenault, J.M.; Lagarde, R.

2005-01-01

French law as regards renunciation to mining concessions calls for the mining operator to first undertake analyses of the risks represented by their underground mining works. The problem of gas migration to the surface is especially significant in the context of coal mines. This is because mine gas can migrate to the earth's surface, then present significant risks: explosion, suffocation or gas poisoning risks. As part of the scheduled closure of all coal mining operations in France, INERIS has drawn up, at the request of national mining operator Charbonnages de France, a general methodology for assessing the risk linked to gas in the context of closed coal mines. This article presents the principles of this methodology. An application example based on a true case study is then described. This is completed by a presentation of the preventive and monitoring resources recommended and usually applied in order to manage the risk linked to gaseous emissions. (authors)

Gas generation by co-gasification of biomass and coal in an autothermal fluidized bed gasifier

International Nuclear Information System (INIS)

Wang, Li-Qun; Chen, Zhao-Sheng

2013-01-01

In this study, thermochemical biomass and coal co-gasification were performed on an autothermal fluidized bed gasifier, with air and steam as oxidizing and gasifying media. The experiments were completed at reaction temperatures of 875 °C–975 °C, steam-to-biomass ratio of 1.2, and biomass-to-coal ratio of 4. This research aims to determine the effects of reaction temperature on gas composition, lower heating value (LHV), as well as energy and exergy efficiencies, of the product gas. Over the ranges of the test conditions used, the product gas LHV varies between 12 and 13.8 MJ/Nm 3 , and the exergy and energy efficiencies of the product gas are in the ranges of 50.7%–60.8% and 60.3%–85.1%, respectively. The results show that high reaction temperature leads to higher H 2 and CO contents, as well as higher exergy and energy efficiencies of the product gas. In addition, gas LHV decreases with temperature. The molar ratio of H 2 /CO is larger than 1 at temperatures above 925 °C. Our experimental analysis shows that co-gasification of biomass and coal in an autothermal fluidized bed gasifier for gas production is feasible and promising. -- Highlights: • An innovative steam co-gasification process for gas production was proposed. • Co-gasification of biomass and coal in an autothermal fluidized bed gasifier was tested. • High temperature favors H 2 production. • H 2 and CO contents increase, whereas CO 2 and CH 4 levels decrease with increase in T. • Exergy and energy efficiencies of gases increase with increase in T

Pra Desain Pabrik Substitute Natural Gas (SNG dari Low Rank Coal

Directory of Open Access Journals (Sweden)

Asti Permatasari

2014-09-01

rendah dan sedang yang sangat banyak, yaitu masing-masing sebesar 2.426,00 juta ton dan 186,00 juta ton. Maka dari itu, pabrik SNG dari low rank coal ini akan didirikan di Kecamatan Ilir Timur, Sumatera Selatan. Rencananya pabrik ini akan didirikan pada tahun 2016 dan siap beroperasi pada tahun 2018. Diperkirakan konsumsi gas alam pada tahun 2018 sebesar 906.599,3 MMSCF sehingga pendirian pabrik yang baru diharapkan dapat menggantikan kebutuhan gas alam sebesar 4% di Indonesia, yaitu sebanyak 36.295,502 MMSCF per tahun atau sebesar 109.986 MMSCFD. Proses pembuatan SNG dari low rank coal terdiri dari empat proses utama, yaitu coal preparation, gasifikasi, gas cleaning, dan metanasi. Dari analisa perhitungan ekonomi didapat Investasi 823.947.924 USD, IRR sebesar 13,12%, POT selama 5 tahun, dan BEP sebesar 68,55%.

Effects of atmospheric gas composition and temperature on the gasification of coal in hot briquetting carbon composite iron ore

Energy Technology Data Exchange (ETDEWEB)

Ueki, Y.; Kanayama, M.; Maeda, T.; Nishika, K.; Shimizu, M. [Kyushu University, Fukuoka (Japan). Dept. of Materials Science & Engineering

2007-01-15

The gasification behavior of carbon composite iron ore produced by hot briquetting process was examined under various gas atmospheres such as CO-N{sub 2}, CO{sub 2}-N, and CO-CO{sub 2} at various temperatures. The gasification of coal was affected strongly by atmospheric gas concentration and reaction temperature. Kinetic analysis in various gas atmospheres was carried out by using the first order reaction model, which yields the straight line relation between reaction rate constants for the gasification of coal and the gas concentration. Therefore, reaction rate constants for the gasification of coal in CO-CO{sub 2}-N{sub 2} gas atmosphere were derived.

Development of standardized air-blown coal gasifier/gas turbine concepts for future electric power systems

Energy Technology Data Exchange (ETDEWEB)

Sadowski, R.S.; Brown, M.J.; Harriz, J.T.; Ostrowski, E.

1991-01-01

The cost estimate provided for the DOE sponsored study of Air Blown Coal Gasification was developed from vendor quotes obtained directly for the equipment needed in the 50 MW, 100 MW, and 200 MW sized plants and from quotes from other jobs that have been referenced to apply to the particular cycle. Quotes were generally obtained for the 100 MW cycle and a scale up/down factor was used to generate the cost estimates for the 200 MW and 50 MW cycles, respectively. Information from GTPro (property of Thermoflow, Inc.) was used to estimate the cost of the 200 MW and 50 MW gas turbine, HRSG, and steam turbines. To available the use of GTPro's estimated values for this equipment, a comparison was made between the quotes obtained for the 100 MW cycle (ABB GT 11N combustion turbine and a HSRG) against the estimated values by GTPro.

Moderate temperature gas purification system: application to high calorific coal derived fuel

Energy Technology Data Exchange (ETDEWEB)

M. Kobayashi; H. Shirai; M. Nunokawa [Central Research Institute of Electric Power Industry (CRIEPI), Kanagawa (Japan)

2005-07-01

Simultaneous removal of dust, alkaline and alkaline-earth metals, halides and sulfur compounds is required to enlarge application of coal-derived gas to the high temperature fuel cells and the fuel synthesis through chemical processing. Because high calorific fuel gas, such as oxygen-blown coal gas, has high carbon monoxide content, high temperature gas purification system is always subjected to the carbon deposition and slippage of contaminant of high vapor pressure. It was suggested that moderate temperature operation of the gas purification system is applied to avoid the harmful disproportionation reaction and efficient removal of the various contaminants. To establish the moderate temperature gas purification system, the chemical-removal processes where the reaction rate is predominant to the performance of contaminant removal should be evaluated. Performance of the removal processes for halides and sulfur compounds were experimentally evaluated. The halide removal process with sodium based sorbent had potential good performance at around 300{sup o}C. The sulfur removal process was also applicable to the temperature range, although the improvement of the sulfidation reaction rate is considered to be essential. 11 refs., 8 figs., 1 tab.

Effect of Colombian coal rank and its feeding technology on substitute natural gas production by entrained gasification

Directory of Open Access Journals (Sweden)

Juan Fernando Pérez-Bayer

2016-01-01

Full Text Available The effect of coal rank (from sub-bituminous to semi-anthracite and type of fuel feeding technology (slurry and dry on the production of substitute natural gas (SNG in entrained flow gasifiers is studied. Ten coals from important Colombian mines were selected. The process is modeled under thermochemical equilibrium using Aspen Plus, and its performance is evaluated in function of output parameters that include SNG heating value, Wobbe index, coal conversion efficiency, cold gas efficiency, process efficiency, global efficiency, and SNG production rate, among others. In descending order, the coal-to-SNG process improves energetically with the use of coals with: higher volatile-matter to fixed-carbon ratio, lower ash content, higher C+H/O ratio, and higher coal heating value. The overall energy efficiency of the slurry-feed technology (S-FT to produce SNG by gasification is 17% higher than the dry-feed technology (D-FT, possibly as a consequence of the higher CH4 concentration in the syngas (around 7 vol. % when the coal is fed as aqueous slurry. As the simulated SNG meets the natural gas (NG quality standards in Colombia, the substitute gaseous fuel could be directly transported through pipelines. Therefore, the coal-to-SNG process is a technically feasible and unconventional alternative for NG production.

Geological Factors and Reservoir Properties Affecting the Gas Content of Coal Seams in the Gujiao Area, Northwest Qinshui Basin, China

Directory of Open Access Journals (Sweden)

Zhuo Zou

2018-04-01

Full Text Available Coalbed methane (CBM well drilling and logging data together with geological data were adopted to provide insights into controlling mechanism of gas content in major coal seams and establish gas accumulation models in the Gujiao area, Northwest Qinshui Basin, China. Gas content of targeted coals is various in the Gujiao area with their burial depth ranging from 295 to 859 m. Highly variable gas content of coals should be derived from the differences among tectonism, magmatism, hydrodynamism, and sedimentation. Gas content preserved in the Gujiao area is divided into two parts by the geological structure. Gas tends to accumulate in the groundwater stagnant zone with a total dissolved solids (TDS value of 1300–1700 ppm due to water pressure in the Gujiao area. Reservoir properties including moisture content, minerals, and pore structure also significantly result in gas content variability. Subsequently, the gray correlation statistic method was adopted to determine the most important factors controlling gas content. Coal metamorphism and geological structure had marked control on gas content for the targeted coals. Finally, the favorable CBM exploitation areas were comprehensively evaluated in the Gujiao area. The results showed that the most favorable CBM exploitation areas were in the mid-south part of the Gujiao area (Block I.

Methanol from coal without CO2 production via the modular high temperature gas-cooled reactor

International Nuclear Information System (INIS)

Schleicher, R.W. Jr.; Engler, D.; Labar, M.P.

1992-01-01

Displacement options for petroleum fuels include natural gas (compressed or liquified), synthetic gasoline, biomass fuels, electric vehicles, hydrogen, and methanol. This paper reports that although no alternative meets all the desired characteristics of economics, environmental impact, supply logistics, and vehicle technology, methanol has often been cited as a good compromise and is perhaps the best coal derived fuel. The main criticism leveled at methanol is whether it can be produced economically in sufficient quantities to significantly displace petroleum-derived fuels. Although methanol can be manufactured from biomass, natural gas or coal feedstocks, only coal offers the potential for a substantial long term indigenous U.S. feedstock

Fractionation of mercury stable isotopes during coal combustion and seawater flue gas desulfurization

International Nuclear Information System (INIS)

Huang, Shuyuan; Yuan, Dongxing; Lin, Haiying; Sun, Lumin; Lin, Shanshan

2017-01-01

In the current study, fractionation of mercury isotopes during coal combustion and seawater flue gas desulfurization (SFGD) in a coal-fired power plant using a SFGD system was investigated. Fourteen samples were collected from the power plant. The samples were pretreated with a combustion-trapping method and were analyzed with a multi-collector inductively coupled plasma mass spectrometer (MC-ICP-MS). Compared with the raw coal, the bottom ash was enriched with lighter mercury isotopes with δ 202 Hg values ranging from −0.45 to −0.03‰. The fly ash was enriched with lighter mercury isotopes with δ 202 Hg values ranging from −1.49 to −0.73‰ for Chinese coal and from −1.47 to −0.62‰ for Indonesian coal. The δ 202 Hg of fresh seawater and desulfurized seawater was found to be −1.32 and −0.32‰ respectively. These δ 202 Hg values indicated that the desulfurized seawater was enriched with heavier mercury isotopes. Based upon the calculated results obtained from the mass balance equation, it was suggested that the stack emissions were enriched with lighter mercury isotopes. Mass independent fractionation was observed in most of the samples with a Δ 199 Hg/Δ 201 Hg ratio of approximately 0.96. The results help in improving the understanding of mercury isotope fractionation during coal combustion and SFGD, and are also useful in tracing the mercury emissions from coal fired power plants. - Highlights: • Spread of 1.5‰ was observed in δ 202 Hg values of raw coals and coal related samples. • The δ 202 Hg values were more negative in fly ash than those in the raw coal. • The flue gas had a significant Hg fractionation after desulfurization. • The stack emissions were enriched with lighter isotopes compared with the raw coal.

FY 2000 report on the results of development of the technologies for recovering and utilizing carbon dioxide using coal and natural gas; 2000 nendo sekitan tennen gas katsuyogata nisanka tanso kaishu riyo gijutsu no kaihatsu seika hokokusho

Energy Technology Data Exchange (ETDEWEB)

NONE

2001-06-01

Described herein are the FY 2000 results of the research and development project for converting the gas, produced by reacting carbon dioxide and water with coal and natural gas using solar ray and heat, into methanol. A solar furnace operating with solar energy, composed of a simulated solar ray collector (5kW), CPC (Compound Parabolic Concentrator), molten salt furnace and coal gasifier, is designed, fabricated and installed. The motion in the molten salt furnace is simulated to analyze the heat flux. The wet and dry type coal gasification processes are simulated with Taiheiyo-coal as the basis. For the natural gas reforming solar furnace, various types of technical information on methane reforming and oxidation catalysts are pigeonholed. The catalytic reaction testing system is fabricated. The information of carbon dioxide separation technologies, e.g., membrane-aided separation, absorption, and membrane/absorption hybrid, is collected. The treatment test with the polyimide-based separation membrane is conducted. The information is pigeonholed and evaluated for development of the elementary techniques and optimization of the total system. The preliminary study on economic viability indicates that methanol production cost is 30 yen/kg-methanol or less, on the basis of releasing no carbon dioxide in the production step. (NEDO)

ADVANCED FLUE GAS CONDITIONING AS A RETROFIT UPGRADE TO ENHANCE PM COLLECTION FROM COAL-FIRED ELECTRIC UTILITY BOILERS

International Nuclear Information System (INIS)

Kenneth E. Baldrey

2002-01-01

The U.S. Department of Energy and ADA Environmental Solutions are engaged in a project to develop commercial flue gas conditioning additives. The objective is to develop conditioning agents that can help improve particulate control performance of smaller or under-sized electrostatic precipitators on utility coal-fired boilers. The new chemicals will be used to control both the electrical resistivity and the adhesion or cohesivity of the fly ash. There is a need to provide cost-effective and safer alternatives to traditional flue gas conditioning with SO(sub 3) and ammonia. During this reporting quarter, performance testing of flue gas conditioning was underway at the PacifiCorp Jim Bridger Power Plant. The product tested, ADA-43, was a combination resistivity modifier with cohesivity polymers. This represents the first long-term full-scale testing of this class of products. Modifications to the flue gas conditioning system at Jim Bridger, including development of alternate injection lances, was also undertaken to improve chemical spray distribution and to avoid spray deposition to duct interior surfaces. Also in this quarter, a firm commitment was received for another long-term test of the cohesivity additives. This plant fires a bituminous coal and has opacity and particulate emissions performance issues related to fly ash re-entrainment. Ammonia conditioning is employed here on one unit, but there is interest in liquid cohesivity additives as a safer alternative

Certification of the contents (mass fraction) of carbon, hydrogen, nitrogen, chlorine, arsenic, cadmium, manganese, mercury, lead, selenium, vanadium and zinc in three coals. Gas coal CRM No. 180; Coking coal CRM No. 181; Steam coal CRM No. 182

Energy Technology Data Exchange (ETDEWEB)

Griepink, B; Colinet, E; Wilkinson, H C

1986-01-01

The report first describes the preparation of three coal reference materials: Gas coal (BCR No. 180), Coking coal (BCR No. 181) and Steam coal (BCR No. 182). It deals further with the homogeneity and stability tests for major, minor and trace components. The contents (mass fractions) of the elements: C, H, N, Cl, As, Cd, Mn, Hg, Pb, Se, V and Zn are certified. The analytical techniques used in the certification are summarised. All the individual results are given and recommendations for analysis are made.

Development of a dry-feed system for a coal-fired gas turbine

Energy Technology Data Exchange (ETDEWEB)

Rothrock, J.W. Jr.; Smith, C.F.

1993-11-01

The objective of the reported of the reported work is to develop a dry coal feed system that provides smooth, controllable flow of coal solids into the high pressure combustor of the engine and all test rigs. The system must start quickly and easily, run continuously with automatic transfer of coal from low pressure hoppers to the high pressure delivery system, and offer at least a 3:1 smooth turn-down ratio. cost of the equipment must be minimized to maintain the economic attractiveness of the whole system. Before the current contract started some work was done with dry powder coal. For safety and convenience reasons, coal water slurry was selected as the fuel for all work on the program. Much of the experimental work, including running the Allison 501-KM engine was done with coal slurry. Recent economic analysis led to a change to powdered coal.

Relations between flash pyrolysis reactivity and oil/gas products from coals of different rank; Sekitankado no kotonaru shushu no sekitan no flash pyrolysis hannosei to gas oyobi eki seiseibutsu no kankei

Energy Technology Data Exchange (ETDEWEB)

Nonaka, T.; Kishino, M.; Sakanishi, K.; Korai, Y.; Mochida, I. [Kyushu University, Fukuoka (Japan). Institute of Advanced Material Study

1996-10-28

Curie point flash pyrolysis (FP) reactivity was studied experimentally using three kinds of coals with different coal ranks such as Yallourn brown coal, Tanitoharum sub-bituminous coal and Wandoan sub-bituminous coal. Experiment was performed using a curie point pyrolyzer in carrier gas of 20ml/min in gas flow rate at 450, 590 and 740{degree}C for 5sec. The experimental results were as follows. Each gas component obviously increased at 450-590{degree}C, however, C4-C6 gases drastically decreased at 590-740{degree}C accompanying reduction of the whole gas quantity. All of each polar component remarkably increased at 450-590{degree}C. Yallourn brown coal with high Owt%, in particular, contained a large amount of alkyl-hydroxybenzene group. The amount of cresol of all of three coal specimens also increased at 740{degree}C. It was thus suggested that this is coal constituent molecules derived from cutting of methylene-ether bridged bond by higher-temperature FP. 8 refs., 5 figs., 3 tabs.

CO{sub 2} abatement policies in the power sector under an oligopolistic gas market

Energy Technology Data Exchange (ETDEWEB)

Hecking, Harald

2014-09-15

The paper at hand examines the power system costs when a coal tax or a fixed bonus for renewables is combined with CO{sub 2} emissions trading. It explicitly accounts for the interaction between the power and the gas market and identifies three cost effects: First, a tax and a subsidy both cause deviations from the cost-efficient power market equilibrium. Second, these policies also impact the power sector's gas demand function as well as the gas market equilibrium and therefore have a feedback effect on power generation quantities indirectly via the gas price. Thirdly, by altering gas prices, a tax or a subsidy also indirectly affects the total costs of gas purchase by the power sector. However, the direction of the change in the gas price, and therefore the overall effect on power system costs, remains ambiguous. In a numerical analysis of the European power and gas market, I find using a simulation model integrating both markets that a coal tax affects gas prices ambiguously whereas a fixed bonus for renewables decreases gas prices. Furthermore, a coal tax increases power system costs, whereas a fixed bonus can decrease these costs because of the negative effect on the gas price. Lastly, the more market power that gas suppliers have, the stronger the outlined effects will be.

Development of a Field Demonstration for Cost-Effective Low-Grade Heat Recovery and Use Technology Designed to Improve Efficiency and Reduce Water Usage Rates for a Coal-Fired Power Plant

Energy Technology Data Exchange (ETDEWEB)

Noble, Russell [Southern Company Services, Incorporated, Birmingham, AL (United States); Dombrowski, K. [AECOM Technical Services, Austin, TX (United States); Bernau, M. [AECOM Technical Services, Austin, TX (United States); Morett, D. [AECOM Technical Services, Austin, TX (United States); Maxson, A. [EPRI, Palo Alto, CA (United States); Hume, S. [EPRI, Palo Alto, CA (United States)

2016-06-30

Coal-based power generation systems provide reliable, low-cost power to the domestic energy sector. These systems consume large amounts of fuel and water to produce electricity and are the target of pending regulations that may require reductions in water use and improvements in thermal efficiency. While efficiency of coal-based generation has improved over time, coal power plants often do not utilize the low-grade heat contained in the flue gas and require large volumes of water for the steam cycle make-up, environmental controls, and for process cooling and heating. Low-grade heat recovery is particularly challenging for coal-fired applications, due in large part to the condensation of acid as the flue gas cools and the resulting potential corrosion of the heat recovery materials. Such systems have also not been of significant interest as recent investments on coal power plants have primarily been for environmental controls due to more stringent regulations. Also, in many regions, fuel cost is still a pass-through to the consumer, reducing the motivation for efficiency improvements. Therefore, a commercial system combining low-grade heat-recovery technologies and associated end uses to cost effectively improve efficiency and/or reduce water consumption has not yet been widely applied. However, pressures from potential new regulations and from water shortages may drive new interest, particularly in the U.S. In an effort to address this issue, the U.S. Department of Energy (DOE) has sought to identify and promote technologies to achieve this goal.

Combustion reactivity of chars from copyrolysis of coal with coke-oven gas

Energy Technology Data Exchange (ETDEWEB)

Liao Hongqiang; Sun Chenggong; Li Baoqing [Chinese Academy of Sciences, Taiyuan (China). State Key Lab. of Coal Conversion

1997-12-31

The combustion reactivity of char from pyrolysis of Xianfeng lignite with coke-oven gas (COG) is related to the pyrolysis pressure and heating rate. Decreasing pressure and increasing heating rate enhance the char yields and combustion reactivity. The combustion reactivities of char from coal pyrolysis with COG nearly reach to that of char from hydropyrolysis, but lower than those of char from coal pyrolysis under N{sub 2}. (orig.)

CATALYTIC GASIFICATION OF COAL USING EUTECTIC SALT MIXTURES; FINAL

International Nuclear Information System (INIS)

Dr. Yaw D. Yeboah; Dr. Yong Xu; Dr. Atul Sheth; Dr. Pradeep Agrawal

2001-01-01

The Gas Research Institute (GRI) estimates that by the year 2010, 40% or more of U.S. gas supply will be provided by supplements including substitute natural gas (SNG) from coal. These supplements must be cost competitive with other energy sources. The first generation technologies for coal gasification e.g. the Lurgi Pressure Gasification Process and the relatively newer technologies e.g. the KBW (Westinghouse) Ash Agglomerating Fluidized-Bed, U-Gas Ash Agglomerating Fluidized-Bed, British Gas Corporation/Lurgi Slagging Gasifier, Texaco Moving-Bed Gasifier, and Dow and Shell Gasification Processes, have several disadvantages. These disadvantages include high severities of gasification conditions, low methane production, high oxygen consumption, inability to handle caking coals, and unattractive economics. Another problem encountered in catalytic coal gasification is deactivation of hydroxide forms of alkali and alkaline earth metal catalysts by oxides of carbon (CO(sub x)). To seek solutions to these problems, a team consisting of Clark Atlanta University (CAU, a Historically Black College and University, HBCU), the University of Tennessee Space Institute (UTSI) and Georgia Institute of Technology (Georgia Tech) proposed to identify suitable low melting eutectic salt mixtures for improved coal gasification. The research objectives of this project were to: Identify appropriate eutectic salt mixture catalysts for coal gasification; Assess agglomeration tendency of catalyzed coal; Evaluate various catalyst impregnation techniques to improve initial catalyst dispersion; Determine catalyst dispersion at high carbon conversion levels; Evaluate effects of major process variables (such as temperature, system pressure, etc.) on coal gasification; Evaluate the recovery, regeneration and recycle of the spent catalysts; and Conduct an analysis and modeling of the gasification process to provide better understanding of the fundamental mechanisms and kinetics of the process

Microbially-Enhanced Coal Bed Methane: Strategies for Increased Biogenic Production

Science.gov (United States)

Davis, K.; Barhart, E. P.; Schweitzer, H. D.; Cunningham, A. B.; Gerlach, R.; Hiebert, R.; Fields, M. W.

2014-12-01

Coal is the largest fossil fuel resource in the United States. Most of this coal is deep in the subsurface making it costly and potentially dangerous to extract. However, in many of these deep coal seams, methane, the main component of natural gas, has been discovered and successfully harvested. Coal bed methane (CBM) currently accounts for approximately 7.5% of the natural gas produced in the U.S. Combustion of natural gas produces substantially less CO2 and toxic emissions (e.g. heavy metals) than combustion of coal or oil thereby making it a cleaner energy source. In the large coal seams of the Powder River Basin (PRB) in southeast Montana and northeast Wyoming, CBM is produced almost entirely by biogenic processes. The in situ conversion of coal to CBM by the native microbial community is of particular interest for present and future natural gas sources as it provides the potential to harvest energy from coal seams with lesser environmental impacts than mining and burning coal. Research at Montana State University has shown the potential for enhancing the subsurface microbial processes that produce CBM. Long-term batch enrichments have investigated the methane enhancement potential of yeast extract as well as algal and cyanobacterial biomass additions with increased methane production observed with all three additions when compared to no addition. Future work includes quantification of CBM enhancement and normalization of additions. This presentation addresses the options thus far investigated for increasing CBM production and the next steps for developing the enhanced in situ conversion of coal to CBM.

Clean Coal Day '94 Hokkaido International Seminar; Clean coal day '94 Hokkaido kokusai seminar

Energy Technology Data Exchange (ETDEWEB)

NONE

1994-06-01

The lectures given at the seminar were 1) Coal energy be friendly toward the earth, 2) Clean coal technology in the United Kingdom, and 3) How clean coal should be in Australia. In lecture 1), remarks are made on the importance of coal and its future, coal that protects forest, whether coal is a dirty fuel, coal combustion tests started relative to environmental pollution, acid rain in China and coal combustion, briquets effective in energy conservation, etc. In lecture 2), remarks are made on the importance of coal utilization in the United Kingdom, current state of coal utilization in power generation, problems related to gasification furnaces, problems related to combustors, problems related to high-temperature gas cleaning, function of cleaning filters, advantages of high-temperature gas treatment, actualities of gas combustors, studies of gas combustors, etc. In lecture 3), remarks are made on Australia's coal situation, problems related to clean coal technology, problems related to coal preparation technology, potentialities of Australian brown coal, coal utilization in power generation, need of new technology development, current state of coal utilization in Australia, coal utilization in metal-making industry, international cooperation on technology, etc. (NEDO)

British Coal and the energy scene

Energy Technology Data Exchange (ETDEWEB)

Cruttenden, M G [British Coal Corporation, London (United Kingdom)

1992-01-01

This paper attempts to describe British Coal's (BCC) present position in a rapidly changing UK Energy Market where competition, with imported coal and with other fuels, particularly natural gas is likely to continue to increase. As a relatively high cost coal producer by world standards BCC, while continuing its efforts to improve productivity and lower costs, must work to enhance the value of its product in the market place both by improving quality to more closely match customers individual needs and by offering supporting services which ensure overall customer satisfaction. The paper explores each market sector and describes the steps which the Corporation is taking to improve its competitive position in each market with particular reference to quality standards and supporting services. Finally it attempts to forecast some possible new developments for the future. 3 tabs.

Method and apparatus for enhancing the desulfurization of hot coal gas in a fluid-bed coal gasifier

Science.gov (United States)

Grindley, T.

1988-04-05

A process and apparatus for providing additional desulfurization of the hot gas produced in a fluid-bed coal gasifier, within the gasifier is described. A fluid-bed of iron oxide is located inside the gasifier above the gasification bed in a fluid-bed coal gasifier in which in-bed desulfurization by lime/limestone takes place. The product gases leave the gasification bed typically at 1600 to 1800 F and are partially quenched with water to 1000 to 1200 F before entering the iron oxide bed. The iron oxide bed provides additional desulfurization beyond that provided by the lime /limestone. 1 fig.

The economical production of alcohol fuels from coal-derived synthesis gas. Quarterly technical progress report No. 4, July 1, 1992--September 30, 1992

Energy Technology Data Exchange (ETDEWEB)

1993-10-01

A base case flow sheet for the production of higher alcohols from coal derived synthesis gas has been completed, including an economic analysis. The details of the flow sheet and economics are in Appendix 1. The pay back period for the capital investment for the plant has been calculated as a function of the market price of the product, and this figure is also shown as Figure I in Appendix 1. The estimated installed cost is almost $500 MM, and the estimated annual operating cost is $64 MM. At a price in the vicinity of $1.00/gal for the alcohol product, the pay back period for construction of the plant is four years. These values should be considered preliminary, since many of the capital costs were obtained from other paper studies sponsored by DOE and TVA and very few values could be found from actual plants which were built. This issue is currently being addressed. The most expensive capital costs were found to be the gasifier, the cryogenic air separation plant, the steam/power generation plant and the acid gas/sulfur removal processes taken as a whole. It is planned to focus attention on alternatives to the base case. The problem is that it is less expensive to make syngas from natural gas. Therefore, it is essential to reduce the cost of syngas from coal. This is where the energy park concept becomes important. In order for this process to be economical (at current market and political conditions) a method must be found to reduce the cost of syngas manufacture either by producing energy or by-products. Energy is produced in the base case, but the amount and method has not been optimized. The economic arguments for this concept are detailed in Appendix 2.

Costly waiting for the future gas energy

International Nuclear Information System (INIS)

1999-01-01

The article discusses solutions while waiting for the pollution free gas power plant and points out that Norway will have to import Danish power from coal and Swedish nuclear energy for a long time yet. Various future scenarios are mentioned

Thermal-maturity limit for primary thermogenic-gas generation from humic coals as determined by hydrous pyrolysis

Science.gov (United States)

Lewan, Michael; Kotarba, M.J.

2014-01-01

Hydrous-pyrolysis experiments at 360°C (680°F) for 72 h were conducted on 53 humic coals representing ranks from lignite through anthracite to determine the upper maturity limit for hydrocarbon-gas generation from their kerogen and associated bitumen (i.e., primary gas generation). These experimental conditions are below those needed for oil cracking to ensure that generated gas was not derived from the decomposition of expelled oil generated from some of the coals (i.e., secondary gas generation). Experimental results showed that generation of hydrocarbon gas ends before a vitrinite reflectance of 2.0%. This reflectance is equivalent to Rock-Eval maximum-yield temperature and hydrogen indices (HIs) of 555°C (1031°F) and 35 mg/g total organic carbon (TOC), respectively. At these maturity levels, essentially no soluble bitumen is present in the coals before or after hydrous pyrolysis. The equivalent kerogen atomic H/C ratio is 0.50 at the primary gas-generation limit and indicates that no alkyl moieties are remaining to source hydrocarbon gases. The convergence of atomic H/C ratios of type-II and -I kerogen to this same value at a reflectance of indicates that the primary gas-generation limits for humic coal and type-III kerogen also apply to oil-prone kerogen. Although gas generation from source rocks does not exceed vitrinite reflectance values greater than , trapped hydrocarbon gases can remain stable at higher reflectance values. Distinguishing trapped gas from generated gas in hydrous-pyrolysis experiments is readily determined by of the hydrocarbon gases when a -depleted water is used in the experiments. Water serves as a source of hydrogen in hydrous pyrolysis and, as a result, the use of -depleted water is reflected in the generated gases but not pre-existing trapped gases.

Coal seam has boom - powering North Queensland industrial growth

Energy Technology Data Exchange (ETDEWEB)

NONE

2005-06-01

Reduced operating costs, lower greenhouse gas emissions and security of supply are being cited by North Queensland industry leaders as the reasons for investing more than A$550 million to expand operations and convert to coal seam gas as their preferred fuel source. The article, by Enertrade, reports that just a few months after commissioning its North Queensland Gas Pipeline to transport coal seam gas from Moranbah to Townsville, Enertrade has signed contracts that will see combined cycle gas-fired baseload electricity generated in Townsville and the Queensland Nickel Refinery, and Xstrata Copper Refinery switch from liquid fuels to gas. The development has been driven by state government policy that 13% of Queensland's electricity be sourced from gas-fired power generation from 1 January 2005. Further information is available from Enertrade on Tel +617 3331 9929. 2 photos.

Clean Coal Technology Demonstration Program. Program update 1994

Energy Technology Data Exchange (ETDEWEB)

NONE

1995-04-01

The Clean Coal Technology Demonstration Program (CCT Program) is a $7.14 billion cost-shared industry/government technology development effort. The program is to demonstrate a new generation of advanced coal-based technologies, with the most promising technologies being moved into the domestic and international marketplace. Clean coal technologies being demonstrated under the CCT program are creating the technology base that allows the nation to meet its energy and environmental goals efficiently and reliably. The fact that most of the demonstrations are being conducted at commercial scale, in actual user environments, and under conditions typical of commercial operations allows the potential of the technologies to be evaluated in their intended commercial applications. The technologies are categorized into four market sectors: advanced electric power generation systems; environmental control devices; coal processing equipment for clean fuels; and industrial technologies. Sections of this report describe the following: Role of the Program; Program implementation; Funding and costs; The road to commercial realization; Results from completed projects; Results and accomplishments from ongoing projects; and Project fact sheets. Projects include fluidized-bed combustion, integrated gasification combined-cycle power plants, advanced combustion and heat engines, nitrogen oxide control technologies, sulfur dioxide control technologies, combined SO{sub 2} and NO{sub x} technologies, coal preparation techniques, mild gasification, and indirect liquefaction. Industrial applications include injection systems for blast furnaces, coke oven gas cleaning systems, power generation from coal/ore reduction, a cyclone combustor with S, N, and ash control, cement kiln flue gas scrubber, and pulse combustion for steam coal gasification.

Characterization of Coal Porosity for Naturally Tectonically Stressed Coals in Huaibei Coal Field, China

Science.gov (United States)

Li, Xiaoshi; Hou, Quanlin; Li, Zhuo; Wei, Mingming

2014-01-01

The enrichment of coalbed methane (CBM) and the outburst of gas in a coal mine are closely related to the nanopore structure of coal. The evolutionary characteristics of 12 coal nanopore structures under different natural deformational mechanisms (brittle and ductile deformation) are studied using a scanning electron microscope (SEM) and low-temperature nitrogen adsorption. The results indicate that there are mainly submicropores (2~5 nm) and supermicropores (coal and mesopores (10~100 nm) and micropores (5~10 nm) in brittle deformed coal. The cumulative pore volume (V) and surface area (S) in brittle deformed coal are smaller than those in ductile deformed coal which indicates more adsorption space for gas. The coal with the smaller pores exhibits a large surface area, and coal with the larger pores exhibits a large volume for a given pore volume. We also found that the relationship between S and V turns from a positive correlation to a negative correlation when S > 4 m2/g, with pore sizes coal. The nanopore structure (coal. PMID:25126601

FY 2000 report on the basic survey to promote Joint Implementation, etc. Project on methane gas recovery use in the Donetsk coal field/coal mine; 2000 nendo kyodo jisshi nado suishin kiso chosa hokokusho. Donetsk tanden tanko methane gas kaishu riyo keikaku

Energy Technology Data Exchange (ETDEWEB)

NONE

2001-03-01

For the purpose of getting petroleum substitution energy and reducing greenhouse effect gas emission, an investigational study was carried out of the project for methane gas recovery/utilization at the Donbassa coal mine in Ukraine. At the Donbassa coal mine, degassing by test boring is being conducted to reduce the gas emission at coal face for safety, but most of the gas is discharged into the air. In this project, the following were studied: degassing boring/gas induction from bore hole/measurement in gas induction pipe, gas recovery system combined with gas induction in flyash, and installation/operation of gas engine power generation facilities (1,710kW x 7 units) with exhaust heat recovery boiler using the recovered methane gas as fuel. The results obtained were the petroleum substitution amount of 31,000 toe/y and the amount of greenhouse effect gas reduction of 480,000 t/y. In the economical estimation, the initial investment amount was 3 billion yen, the profitability of the total investment used was 2.9%, and the internal earning rate was 6.5%. (NEDO)

COST EFFECTIVE REGULATORY APPROACHES TO ENHANCE DOMESTIC OIL & GAS PRODUCTION AND ENSURE THE PROTECTION OF THE ENVIRONMENT

Energy Technology Data Exchange (ETDEWEB)

Ben Grunewald; Paul Jehn; Tom Gillespie; Ben Binder

2004-12-21

The Environmental Information Management Suite/Risk Based Data Management System (EIMS/RBDMS) and Cost Effective Regulatory Approach (CERA) programs continue to be successful. All oil and gas state regulatory programs participate in these efforts. Significant accomplishments include: streamline regulatory approaches, enhancing environmental protection, and making oil and gas data available via the Internet. Oil and gas companies worldwide now have access to data on state web sites. This reduces the cost of exploration and enables companies to develop properties in areas that would have been cost prohibited for exploration. Early in project, GWPC and State Oil and Gas agencies developed the EIMS and CERA strategic plan to prioritize long term development and implementation. The planning process identifies electronic commerce and coal bed methane as high priorities. The group has involved strategic partners in industry and government to develop a common data exchange process. Technical assistance to Alaska continues to improve their program management capabilities. New initiatives in Alaska include the development of an electronic permit tracking system. This system allows managers to expedite the permitting process. Nationwide, the RBDMS system is largely completed with 22 states and one Indian Nation now using this nationally accepted data management system. Additional remaining tasks include routine maintenance and the installation of the program upon request for the remaining oil and gas states. The GWPC in working with the BLM and MMS to develop an XML schema to facilitate electronic permitting and reporting (Appendix A, B, and C). This is a significant effort and, in years to come, will increase access to federal lands by reducing regulatory barriers. The new initiatives are coal bed methane and e-commerce. The e-commerce program will provide industry and BLM/MMS access to the millions of data points housed in the RBDMS system. E-commerce will streamline

Adsorption of iodine from COIL waste gas on soaked coal-based activated carbon

Science.gov (United States)

Zhou, Junbo; Hao, Shan; Gao, Liping

2014-04-01

The chemical oxygen-iodine laser (COIL) has wide application prospects in military, industrial and medical treatment fields as a second generation gas chemical laser to follow the first HF/DF chemical laser. However, a COIL releases large amounts of gas, such as helium, oxygen, chlorine and iodine. Chlorides have a serious corrosive effect on the system, especially iodine vapor crystallization, which seriously endangers the normal use of vacuum systems, and radioactive methyl iodide, which is hazardous to operators and pollutes the environment. The use of soaked coal-based activated carbon as an adsorbent for removing methyl iodine is proposed, while it is proposed that coal-based activated carbon is an effective adsorbent for removing stable iodine. The research conducted in this work shows that iodine residues are less than 0.5 μg ml-1 after the adsorption treatment and the decontamination factor of the coal-based activated carbon for removing stable iodine is more than 1000. Using this method can achieve the purpose of removing harmful iodine, satisfy the requirements for engineering applications, and also be applied to other nuclear power plant flue gas treatments.

Investigation into the potential for dust and gas explosions in underground coal mines with reference to pick tip geometry

International Nuclear Information System (INIS)

Dawood, Albert D.

2011-01-01

In underground coal mines, methane gas, if present in sufficient concentration, may be ignited by sparks from hot spots on the picks of coal cutting machines striking hard bands of rock. During the coal cutting, wear-flat areas develop on the trailing side of the tips of picks. As pick wear progresses, the generation of frictional heat and coal dust increases and the development of hot spots at the cutting tips may lead to an explosion of methane gas. Field experience and research work over the last few years have facilitated excellent cutting performance for certain picks through the optimisation of the cutting parameters. Such performance improvements show great promise in preventing the incidence of gas or dust explosions occurring at the coal face area. This study sets out some of the fundamentals of pick geometry and cutting parameters and the methods which have been employed to achieve improvements in reducing the hazards of gas or dust explosions. It is based on the comparative trial results of two types of picks with different designs and on a range of available research information on the subject. My investigation looked at the fundamentals of pick geometry and cutting parameters and the current suppression techniques in place to control the dust and gas explosions on the coal operating face.

Comparison of electricity production costs of nuclear and coal-fired power plants

International Nuclear Information System (INIS)

Peltzer, M.

1980-01-01

Electricity production costs of nuclear and coal-fired power plants their structure and future development are calculated and compared. Assumed beginning of operation is in the mid-1980. The technical and economical data are based on a nuclear power unit of 1 300 MW and on a coal-fired twin plant of 2 x 750 MW. The study describes and discusses the calculational method and the results. The costs for the electricity generation show an economic advantage for nuclear power. A sensitivity analysis shows that these results are valid also for changed input parameters. (orig.) [de

Dew point of flue gas in the combustion of brown coal briquettes

Energy Technology Data Exchange (ETDEWEB)

Schinkel, W

1977-08-01

Economical operation of small steam generators can follow two courses, viz. to channel the emitted gases through the plant and reduce waste gas loss. Two possibilities exist to achieve this: firstly a steam generating process with only slight excess air; secondly a reduction of the emitted gas temperature. The lowest waste gas temperature found in sulphur-containing combustion materials is measured by finding the acid dew-point of the waste gas. The following results in the case of brown coal briquettes were found. Measurements of the dew point of flue gas in two steam generators, both of the double flue type, one having a capacity of 12.5 t/h, the other 25 t/h, one using brown coal briquettes with 1% sulphur content, the other with 3%, resulted in the fact that the dew point can be measured. It was shown that a low air ratio leads to a lowering of the dew point. However this process is unfortunately economically unviable in chain grate generators as the waste gas becomes so thin under a high air ratio that the dew point can only be minimally reduced. Further the acid dew point is only slightly influenced by partial operation of the generator and the infusion of briquette residue.

Nuclear Energy Cost Data Base: A reference data base for nuclear and coal-fired powerplant power generation cost analysis

International Nuclear Information System (INIS)

Delene, J.G.; Bowers, H.I.

1986-12-01

A reference data base and standard methodology are needed for performing comparative nuclear and fossil power generation cost analyses for the Department of Energy, Office of Nuclear Energy. This report contains such a methodology together with reference assumptions and data to be used with the methodology. It is intended to provide basic guidelines or a starting point for analyses and to serve as a focal point in establishing parameters and methods to be used in economic comparisons of nuclear systems with alternatives. The data base is applicable for economic comparisons of new base load light-water reactors on either the current once-through cycle or self-generated recycle, high- and low-sulfur coal-fired plants, and oil- and natural gas-fired electric generating plants coming on line around the turn of the century. In additions to light-water reactors and fossil fuel-fired plants, preliminary cost information is also presented on liquid metal reactor plants. This report includes a data base containing proposed technical and economic assumptions to be used in analyses, discussions of recommended methodology to be used in calculating power generation costs, and a sample calculation for illustrative benchmark purposes

Nuclear Energy Cost Data Base: a reference data base for nuclear and coal-fired powerplant power generation cost analysis

International Nuclear Information System (INIS)

1985-06-01

A reference data base and standard methodology are needed for performing comparative nuclear and fossil power generation cost analyses for the Department of Energy, Office of Nuclear Energy. This report contains such a methodology together with reference assumptions and data to be used with the methodology. It is intended to provide basic guidelines or a starting point for analyses and to serve as a focal point in establishing parameters and methods to be used in economic comparisons of nuclear systems with alternatives. The data base is applicable for economic comparisons of new base load light-water reactors on either the current once-through cycle or self-generated recycle, high- and low-sulfur coal-fired plants, and oil- and natural gas-fired electric generating plants coming on line in the last decade of this century. In addition to light-water reactors and fossil fuel-fired plants, preliminary cost information is also presented on liquid metal reactor plants. This report includes a data base containing proposed technical and economic assumptions to be used in analyses, discussions of a recommended methodology to be used in calculating power generation costs, and a sample calculation for illustrative and benchmark purposes

Economic competitiveness of small modular reactors versus coal and combined cycle plants

International Nuclear Information System (INIS)

Alonso, Gustavo; Bilbao, Sama; Valle, Edmundo del

2016-01-01

Small modular reactors (SMRs) may be an option to cover the electricity needs of isolated regions, distributed generation grids and countries with small electrical grids. Previous analyses show that the overnight capital cost for SMRs is between 4500 US$/kW and 5350 US$/kW, which is between a 6% and a 26% higher than the average cost of a current large nuclear reactor. This study analyzes the economic competitiveness of small modular reactors against thermal plants using coal and natural gas combined cycle plants. To assess the economic competitiveness of SMRs, three overnight capital costs are considered 4500 US$/kW, 5000 US$/kW and 5350 US$/kW along with three discount rates for each overnight cost considered, these are 3, 7, and 10%. To compare with natural gas combined cycle (CC) units, four different gas prices are considered, these are 4.74 US$/GJ (5 US$/mmBTU), 9.48 US$/GJ (10 US$/mmBTU), 14.22 US$/GJ (15 US$/mmBTU), and 18.96 US$/GJ (20 US$/mmBTU). To compare against coal, two different coal prices are considered 80 and 120 US$/ton of coal. The carbon tax considered, for both CC and coal, is 30 US$/ton CO_2. The results show what scenarios make SMRs competitive against coal and/or combined cycle plants. In addition, because the price of electricity is a key component to guarantee the feasibility of a new project, this analysis calculates the price of electricity for the economically viable deployment of SMRs in all the above scenarios. In particular, this study shows that a minimum price of electricity of 175 US$/MWh is needed to guarantee the feasibility of a new SMR, if its overnight capital cost is 5350 US$/kWe and the discount rate is 10%. Another result is that when the price of electricity is around 100 US$/MWh then the discount rate must be around 7% or less to provide appropriate financial conditions to make SMRs economically feasible. - Highlights: • Small modular reactor (SMR) are economically assessed. • SMR are compared against gas and coal

Wyoming coal-conversion project. Final technical report, November 1980-February 1982. [Proposed WyCoalGas project, Converse County, Wyoming; contains list of appendices with title and identification

Energy Technology Data Exchange (ETDEWEB)

None

1982-01-01

This final technical report describes what WyCoalGas, Inc. and its subcontractors accomplished in resolving issues related to the resource, technology, economic, environmental, socioeconomic, and governmental requirements affecting a project located near Douglas, Wyoming for producing 150 Billion Btu per day by gasifying sub-bituminous coal. The report summarizes the results of the work on each task and includes the deliverables that WyCoalGas, Inc. and the subcontractors prepared. The co-venturers withdrew from the project for two reasons: federal financial assistance to the project was seen to be highly uncertain; and funds were being expended at an unacceptably high rate.

Enhanced Coal Bed Methane Recovery and CO2 Sequestration in the Powder River Basin

Energy Technology Data Exchange (ETDEWEB)

Eric P. Robertson

2010-06-01

Unminable coal beds are potentially large storage reservoirs for the sequestration of anthropogenic CO2 and offer the benefit of enhanced methane production, which can offset some of the costs associated with CO2 sequestration. The objective of this report is to provide a final topical report on enhanced coal bed methane recovery and CO2 sequestration to the U.S. Department of Energy in fulfillment of a Big Sky Carbon Sequestration Partnership milestone. This report summarizes work done at Idaho National Laboratory in support of Phase II of the Big Sky Carbon Sequestration Partnership. Research that elucidates the interaction of CO2 and coal is discussed with work centering on the Powder River Basin of Wyoming and Montana. Sorption-induced strain, also referred to as coal swelling/shrinkage, was investigated. A new method of obtaining sorption-induced strain was developed that greatly decreases the time necessary for data collection and increases the reliability of the strain data. As coal permeability is a strong function of sorption-induced strain, common permeability models were used to fit measured permeability data, but were found inadequate. A new permeability model was developed that can be directly applied to coal permeability data obtained under laboratory stress conditions, which are different than field stress conditions. The coal permeability model can be used to obtain critical coal parameters that can be applied in field models. An economic feasibility study of CO2 sequestration in unminable coal seams in the Powder River Basin of Wyoming was done. Economic analyses of CO2 injection options are compared. Results show that injecting flue gas to recover methane from CBM fields is marginally economical; however, this method will not significantly contribute to the need to sequester large quantities of CO2. Separating CO2 from flue gas and injecting it into the unminable coal zones of the Powder River Basin seam is currently uneconomical, but can

Coal liquefaction and gas conversion contractors review conference: Proceedings

Energy Technology Data Exchange (ETDEWEB)

NONE

1995-11-01

This volume contains 55 papers presented at the conference. They are divided into the following topical sections: Direct liquefaction; Indirect liquefaction; Gas conversion (methane conversion); and Advanced research liquefaction. Papers in this last section deal mostly with coprocessing of coal with petroleum, plastics, and waste tires, and catalyst studies. Selected papers are indexed separately for inclusion in the Energy Science and Technology Database.

Greenhouse gas implications of using coal for transportation: Life cycle assessment of coal-to-liquids, plug-in hybrids, and hydrogen pathways

International Nuclear Information System (INIS)

Jaramillo, Paulina; Samaras, Constantine; Wakeley, Heather; Meisterling, Kyle

2009-01-01

Using coal to produce transportation fuels could improve the energy security of the United States by replacing some of the demand for imported petroleum. Because of concerns regarding climate change and the high greenhouse gas (GHG) emissions associated with conventional coal use, policies to encourage pathways that utilize coal for transportation should seek to reduce GHGs compared to petroleum fuels. This paper compares the GHG emissions of coal-to-liquid (CTL) fuels to the emissions of plug-in hybrid electric vehicles (PHEV) powered with coal-based electricity, and to the emissions of a fuel cell vehicle (FCV) that uses coal-based hydrogen. A life cycle approach is used to account for fuel cycle and use-phase emissions, as well as vehicle cycle and battery manufacturing emissions. This analysis allows policymakers to better identify benefits or disadvantages of an energy future that includes coal as a transportation fuel. We find that PHEVs could reduce vehicle life cycle GHG emissions by up to about one-half when coal with carbon capture and sequestration is used to generate the electricity used by the vehicles. On the other hand, CTL fuels and coal-based hydrogen would likely lead to significantly increased emissions compared to PHEVs and conventional vehicles using petroleum-based fuels.

ESTIMATION OF NEAR SUBSURFACE COAL FIRE GAS EMISSIONS BASED ON GEOPHYSICAL INVESTIGATIONS

Science.gov (United States)

Chen-Brauchler, D.; Meyer, U.; Schlömer, S.; Kus, J.; Gundelach, V.; Wuttke, M.; Fischer, C.; Rueter, H.

2009-12-01

Spontaneous and industrially caused subsurface coal fires are worldwide disasters that destroy coal resources, cause air pollution and emit a large amount of green house gases. Especially in developing countries, such as China, India and Malaysia, this problem has intensified over the last 15 years. In China alone, 10 to 20 million tons of coal are believed to be lost in uncontrolled coal fires. The cooperation of developing countries and industrialized countries is needed to enforce internationally concerted approaches and political attention towards the problem. The Clean Development Mechanism (CDM) under the framework of the Kyoto Protocol may provide an international stage for financial investment needed to fight the disastrous situation. A Sino-German research project for coal fire exploration, monitoring and extinction applied several geophysical approaches in order to estimate the annual baseline especially of CO2 emissions from near subsurface coal fires. As a result of this project, we present verifiable methodologies that may be used in the CDM framework to estimate the amount of CO2 emissions from near subsurface coal fires. We developed three possibilities to approach the estimation based on (1) thermal energy release, (2) geological and geometrical determinations as well as (3) direct gas measurement. The studies involve the investigation of the physical property changes of the coal seam and bedrock during different burning stages of a underground coal fire. Various geophysical monitoring methods were applied from near surface to determine the coal volume, fire propagation, temperature anomalies, etc.

U.S. DOE indirect coal liquefaction program: An overview

Energy Technology Data Exchange (ETDEWEB)

Shen, J.; Schmetz, E.; Winslow, J.; Tischer, R. [Dept. of Energy, Germantown, MD (United States); Srivastava, R.

1997-12-31

Coal is the most abundant domestic energy resource in the United States. The Fossil Energy Organization within the US Department of Energy (DOE) has been supporting a coal liquefaction program to develop improved technologies to convert coal to clean and cost-effective liquid fuels to complement the dwindling supply of domestic petroleum crude. The goal of this program is to produce coal liquids that are competitive with crude at $20 to $25 per barrel. Indirect and direct liquefaction routes are the two technologies being pursued under the DOE coal liquefaction program. This paper will give an overview of the DOE indirect liquefaction program. More detailed discussions will be given to the F-T diesel and DME fuels which have shown great promises as clean burning alternative diesel fuels. The authors also will briefly discuss the economics of indirect liquefaction and the hurdles and opportunities for the early commercial deployment of these technologies. Discussions will be preceded by two brief reviews on the liquid versus gas phase reactors and the natural gas versus coal based indirect liquefaction.

Electric plants to gas, influence of both Mineral Matter and Air Oxidation in coal pyrolysis

International Nuclear Information System (INIS)

Mondragon, F.; Jaramillo, A.; Quintero, G.

1995-01-01

In this work some coal samples from different Colombia's deposits are analyzed. In first stage, material matter is removed from coal by acid treatment with HF/HCl, and aerial oxidation of coal is made with air in oven to 150 Centigrade degree temperature. In second stage, pyrolysis is carried out in two different techniques: 1. Thermogravimetric Analysis (TGA) and 2. Programmed Temperature Pyrolysis (PTP) in a pyrolyzer equipped with a quadrupole mass spectrometer. In both techniques, the coal samples are heated in different rates to 650 Centigrade degree. During PTP trials the evolution of CH4, H2S, hydrocarbons (m/z=42), CO2, benzene and toluene are monitored. Studied coal samples showed: 1). A gas conversion range between 48.8% to 21.8%; 2). A decrease in the gas conversion between 2% to 4%, when oxidation it is applied; 3). The temperature at the one which is presented the maximum evolution of CH4 is similar for all coal samples; 4). The maximum evolution of H2S depends on mineral matter composition, occurs between 480 to 550 Centigrade degrees and is presented due to pyrite decomposition. 5). The evolution of CO2 occurs between 100 to 650 Centigrade degree, its production is generated in different stage of the mentioned temperature range, and in some coal samples is presented due to inorganic origin

Coal Transition in the United States. An historical case study for the project 'Coal Transitions: Research and Dialogue on the Future of Coal'

International Nuclear Information System (INIS)

Kok, Irem

2017-01-01

This is one of the 6 country case-studies commissioned to collect experience on past coal transitions. The 6 countries are: Czech Republic, the Netherlands, Poland, Spain, UK, USA. Their role in the Coal Transitions project was to provide background information for a Synthesis Report for decision makers, and provide general lessons for national project teams to take into account in developing their coal transitions pathways for the future. Over the past decade, the US started to cut down the production and the use of coal, which was affected by unfavorable market dynamics and changing federal regulatory environment. Even before the shale gas revolution and uptake of renewables diminish the use of coal in power generation, coal communities were struggling to meet ends. The regional cost differences between producing states, such as the Appalachian and the Powder River Basins, indicates that coal-impacted communities and workers have lived through the impacts of coal transition at varying magnitudes and time periods. In the period between 2014 and 2016, we have seen the crash of major US coal companies due to declining demand for US coal domestically and internationally. Furthermore, Obama administration's climate change policies negatively impacted coal-fired power plants with additional GHG emission requirements, contributing to declining domestic demand for coal. Combined with market downturn, US coal producers already struggle to pay for high operational costs and legal liabilities under bankruptcy conditions. With under-funded state budgets, coal states are also grappling with financial exposure resulting from pension, health care and reclamation liabilities of bankrupt coal companies. In 2016, former President Obama announced the Power Plus Plan to aid coal-impacted communities and workers to prepare for a low carbon future. The federal budget plan targeted diversification of local economies, funding of health and pension funds of miners and retraining for

Combustion of producer gas from gasification of south Sumatera lignite coal using CFD simulation

Directory of Open Access Journals (Sweden)

Vidian Fajri

2017-01-01

Full Text Available The production of gasses from lignite coal gasification is one of alternative fuel for the boiler or gas turbine. The prediction of temperature distribution inside the burner is important for the application and optimization of the producer gas. This research aims to provide the information about the influence of excess air on the temperature distribution and combustion product in the non-premixed burner. The process was carried out using producer gas from lignite coal gasification of BA 59 was produced by the updraft gasifier which is located on Energy Conversion Laboratory Mechanical Engineering Department Universitas Sriwijaya. The excess air used in the combustion process were respectively 10%, 30% and 50%. CFD Simulations was performed in this work using two-dimensional model of the burner. The result of the simulation showed an increase of excess air, a reduction in the gas burner temperature and the composition of gas (carbon dioxide, nitric oxide and water vapor.

Adult Education and Radical Habitus in an Environmental Campaign: Learning in the Coal Seam Gas Protests in Australia

Science.gov (United States)

Ollis, Tracey; Hamel-Green, Michael

2015-01-01

This paper examines the adult learning dimensions of protestors as they participate in a campaign to stop coal seam gas exploration in Gippsland in Central Victoria, Australia. On a global level, the imposition of coal seam gas exploration by governments and mining companies has been the trigger for movements of resistance from environmental…

Depth treatment of coal-chemical engineering wastewater by a cost-effective sequential heterogeneous Fenton and biodegradation process.

Science.gov (United States)

Fang, Yili; Yin, Weizhao; Jiang, Yanbin; Ge, Hengjun; Li, Ping; Wu, Jinhua

2018-05-01

In this study, a sequential Fe 0 /H 2 O 2 reaction and biological process was employed as a low-cost depth treatment method to remove recalcitrant compounds from coal-chemical engineering wastewater after regular biological treatment. First of all, a chemical oxygen demand (COD) and color removal efficiency of 66 and 63% was achieved at initial pH of 6.8, 25 mmol L -1 of H 2 O 2 , and 2 g L -1 of Fe 0 in the Fe 0 /H 2 O 2 reaction. According to the gas chromatography-mass spectrometer (GC-MS) and gas chromatography-flame ionization detector (GC-FID) analysis, the recalcitrant compounds were effectively decomposed into short-chain organic acids such as acetic, propionic, and butyric acids. Although these acids were resistant to the Fe 0 /H 2 O 2 reaction, they were effectively eliminated in the sequential air lift reactor (ALR) at a hydraulic retention time (HRT) of 2 h, resulting in a further decrease of COD and color from 120 to 51 mg L -1 and from 70 to 38 times, respectively. A low operational cost of 0.35 $ m -3 was achieved because pH adjustment and iron-containing sludge disposal could be avoided since a total COD and color removal efficiency of 85 and 79% could be achieved at an original pH of 6.8 by the above sequential process with a ferric ion concentration below 0.8 mg L -1 after the Fe 0 /H 2 O 2 reaction. It indicated that the above sequential process is a promising and cost-effective method for the depth treatment of coal-chemical engineering wastewaters to satisfy discharge requirements.

Effects of new environmental regulations on coal-fired generation

International Nuclear Information System (INIS)

LaCount, R.

1999-01-01

As restructuring of the electricity industry places downward pressure on power production costs, new environmental regulations are having the opposite effect. Although power plants may be subject to a variety of environmental regulations over the next ten years including reductions in mercury, toxics, and carbon dioxide, new regulations for sulfur dioxide (SO2) and nitrogen oxides (NOX) are poised to impact the electricity industry in the very short term. The cost for coal-fired power plants to comply with these new regulations has the potential to alter their competitive position. January 1, 2000 marks the beginning of Phase II for the Environmental Protection Agency's SO2 allowance market. Starting in January, all coal and oil plants above 25 MW will be required to comply with the federal SO2 provisions. Regulatory deadlines for NOX are also fast approaching; though the ultimate requirements are still subject to change. On May 1, 1999, a NOX allowance market began for states within the Northeast Ozone Transport Commission (OTC). A second phase of this program is scheduled to begin in 2003 that will lower the overall cap for allowable NOX emissions in the participating states. EPA is also working to expand the reach of regional NOX reductions in 2003 through its NOX SIP call. This program, which is currently subject to litigation, would require NOX reductions in 14 states outside of the OTC. A new study by Resource Data International (RDI), Coal-Fired Generation in Competitive Power Markets, assessed the potential impact that the new SO2 and NOX regulations may have on the competitiveness of coal-fired generation. Overall, the study shows that coal-fired generation will continue to grow despite significant environmental costs and competition from natural gas-fired units. The new environmental regulations have the effect of increasing the dispatch cost of coal-fired units from $0.65/MWh on average in the WSCC to $4.14/MWh on average in the MAAC region. The addition

Monetization of External Costs Using Lifecycle Analysis—A Comparative Case Study of Coal-Fired and Biomass Power Plants in Northeast China

Directory of Open Access Journals (Sweden)

Lingling Wang

2015-02-01

Full Text Available In this study, the structures of external costs are built in line with coal-fired and biomass power plant life cycle activities in Northeast China. The external cost of coal-fired and biomass power plants was compared, using the lifecycle approach. In addition, the external costs of a biomass power plant are calculated for each stage for comparison with those of a coal-fired power plant. The results highlight that the external costs of a coal-fired plant are 0.072 US $/kWh, which are much higher than that of a biomass power plant, 0.00012 US$/kWh. The external cost of coal-fired power generation is as much as 90% of the current price of electricity generated by coal, while the external cost of a biomass power plant is 1/1000 of the current price of electricity generated by biomass. In addition, for a biomass power plant, the external cost associated with SO2, NOX, and PM2.5 are particularly lower than those of a coal-fired power plant. The prospect of establishing precise estimations for external cost mechanisms and sustainable energy policies is discussed to show a possible direction for future energy schemes in China. The paper has significant value for supporting the biomass power industry and taxing or regulating coal-fired power industry to optimize the energy structure in China.

Key Technologies and Applications of Gas Drainage in Underground Coal Mine