Gasification technology assessment of sterile coal to clean electrical power generation.

Sterile coal is a low-value residue associated to the coal extraction and mining activity. According to the type and origin of the coal bed configuration, sterile coal production can mainly vary on quantity, calorific value and presence of sulphur compounds. In addition, the potential availability of sterile coal within Spain is apparently high and its contribution to the local power generation would be of interest playing a significant role. The proposed study evaluates the availability and deployment of gasification technologies to drive clean electricity generation from waste coal and sterile rock coal, incorporating greenhouse gas emission mitigation systems, like CO2, H2S and NOx removal systems. It establishes the target facility and its conceptual basic design proposal. The syngas obtained after the gasification of sterile coal is processed through specific conditioning units before entering into the combustion chamber of a gas turbine. Flue gas leaving the gas turbine is ducted to a heat recovery steam generation boiler; the steam produced within the boilerdrives a steam turbine. The target facility resembles a singular Integrated Gasification in Combined Cycle (IGCC) power station. The evaluation of the conceptual basic design according to the power output set for a maximum sterile contribution, established that rates over 95% H2S and 90% CO2 removal can be achieved. Noticeable decrease of NOx compounds can be also achieved by the use of commercial technology. A techno-economic approach of the conceptual basic design is made evaluating the integration of potential unitsand their implementation within the target facility aiming toachieve clean power generation. The criterion to be compliant with the most restrictive regulation regarding environmental emissions is setting to carry out this analysis.

Distribution of the coal flow in the mill-duct system of the As Pontes Power Plant using CFD modeling

The efficiency of a Power Plant is affected by the distribution of the pulverized coal within the furnace. The coal, which is pulverized in the mills, is transported and distributed by the primary gas through the mill-ducts to the interior of the furnace. This is done with a double function: dry and enter the coal by different levels for optimizing the combustion in the sense that a complete combustion occurs with homogeneous heat fluxes to the walls. The mill-duct systems of a real Power Plant are very complex and they are not yet well understood. In particular, experimental data concerning the mass flows of coal to the different levels are very difficult to measure. CFD modeling can help to determine them. An Eulerian/Lagrangian approach is used due to the low solid–gas volume ratio.

Numerical simulation of group combustion of pulverized coal

A mathematical model for the group combustion of pulverized coal particles was developed in a previous work. It includes the Lagrangian description of the dehumidification, devolatilization and char gasification reactions of the coal particles in the homogenized gaseous environment resulting from the three fuels, CO, H2 and volatiles, supplied by the gasification of the particles and their simultaneous group combustion by the gas phase oxidation reactions, which are considered to be very fast. This model is complemented here with an analysis of the particle dynamics, determined principally by the effects of aerodynamic drag and gravity, and its dispersion based on a stochastic model. It is also extended to include two other simpler models for the gasification of the particles: the first one for particles small enough to extinguish the surrounding diffusion flames, and a second one for particles with small ash content when the porous shell of ashes remaining after gasification of the char, non structurally stable, is disrupted. As an example of the applicability of the models, they are used in the numerical simulation of an experiment of a non-swirling pulverized coal jet with a nearly stagnant air at ambient temperature, with an initial region of interaction with a small annular methane flame. Computational algorithms for solving the different stages undergone by a coal particle during its combustion are proposed. For the partial differential equations modeling the gas phase, a second order finite element method combined with a semi-Lagrangian characteristics method are used. The results obtained with the three versions of the model are compared among them and show how the first of the simpler models fits better the experimental results.

Kyiv's gas strategy: closer cooperation with Gazprom or a genuine diversification. OSW Commentary No. 110, 2013-07-16

In recent months Kyiv has been intensifying its efforts to diversify Ukraine’s gas supply routes with a view to reducing the country’s dependence on imports from Russia. One of the steps which Kyiv has taken has been to make the unprecedented decision to start importing gas from its Western neighbours. In November 2012, Ukraine’s state-owned Naftogaz began importing gas through Poland under a two-month contract with RWE (the imports continued into 2013 under a separate deal), while in the spring of 2013 Ukraine started importing gas from Hungary. Kyiv is also currently looking into the possibility of purchasing gas from Slovakia. Furthermore, since 2010 the Ukrainian government has been working on the construction of an LNG terminal near Odesa. The authorities have declared that this will allow Ukraine to import up to 5 billion m3 of LNG a year by 2015. The government has also taken measures to increase domestic production, including from non-traditional sources, and it plans to replace gas-based with coal-based technologies in local power stations. Finally, in January 2013, the government signed a 50-year production sharing agreement with Shell. This paves the way for the development of Ukraine’s shale gas deposits.

First steps towards into the unknown. The possibilities prospects of unconventional gas extraction in Ukraine. OSW Commentary No. 106, 2013-04-24

Ukraine’s deposits of unconventional gas (shale gas, tight gas trapped in non-porous sandstone formations, and coal bed methane) may form a significant part of Europe’s gas reserves. Initial exploration and test drilling will be carried out in two major deposits: Yuzivska (Kharkiv and Donetsk Oblasts) and Oleska (Lviv and Ivano-Frankivsk Oblasts), to confirm the volume of the reserves. Shell and Chevron, respectively, won the tenders for the development of these fields in mid 2012. Gas extraction on an industrial scale is expected to commence in late 2018/ early 2019 at the earliest. According to estimates presented in the draft Energy Strategy of Ukraine 2030, annual gas production levels may range between 30 billion m3 and 47 billion m3 towards the end of the next decade. According to optimistic forecasts from IHS CERA, total gas production (from both conventional and unconventional reserves) could reach as much as 73 billion m3. However, this will require multi-billion dollar investments, a significant improvement in the investment climate, and political stability. It is clear at the present initial stage of the unconventional gas extraction project that the private interests of the Ukrainian government elite have played a positive role in initiating unconventional gas extraction projects. Ukraine has had to wait nearly four decades for this opportunity to regain its status of a major gas producer. Gas from unconventional sources may lead not only to Ukraine becoming self-sufficient in terms of energy supplies, but may also result in it beginning to export gas. Furthermore, shale gas deposits in Poland and Ukraine, including on the Black Sea shelf (both traditional natural gas and gas hydrates) form a specific ‘European methane belt’, which could bring about a cardinal change in the geopolitics and geo-economics of Eastern and Central Europe over the next thirty years.

German companies strengthen their cooperation with Russian gas suppliers. OSW Commentary No. 64, 2011-10-24

Germany’s decision to give up the use of nuclear energy will force it to find a conventional low-carbon energy source as a replacement; in the short term, in addition to coal, this is likely to be gas. Due to their continued high debt and the losses associated with the end of atomic power, German companies will not be able to spend large funds on investing in conventional energy. First of all, they will aim to raise capital and repay their debts. The money for this will come from selling off their less profitable assets; this will include sales on the gas market. This will create opportunities for natural gas exporters and extraction companies such as Gazprom to buy back some of the German companies’ assets (electricity companies, for example). The German companies will probably continue to seek to recover the costs incurred in the investment projects already underway, such as Nord Stream, the importance of which will grow after Russian gas imports increase. At the same time, because of their debts, the German companies will seek to minimise their investment costs by selling some shares on the conventional energy market, to Russian corporations among others; the latter would thus be able to increase their stake in the gas market in both Western (Germany, Great Britain, the Benelux countries) and Central Europe (Poland, the Czech Republic). It is possible that while establishing the details of cooperation between the Russian and German companies, Russia will try to put pressure on Germany to give up competing projects such as Nabucco. However, a well-diversified German energy market should be able to defend itself against attempts to increase German dependence on Russian gas supplies and the dictates of high prices.

The uncertain future of the coal energy industry in Germany. OSW COMMENTARY #188, 2015-10-20

Germany’s current energy strategy, known as the “energy transition”, or Energiewende, involves an accelerated withdrawal from the use of nuclear power plants and the development of renewable energy sources (RES). According to the government’s plans, the share of RES in electricity production will gradually increase from its present rate of 26% to 80% in 2050. Greenhouse gas emissions are expected to fall by 80–95% by 2050 when compared to 1990 levels. However, coal power plants still predominate in Germany’s energy mix – they produced 44% of electricity in 2014 (26% from lignite and 18% from hard coal). This makes it difficult to meet the emission reduction objectives, lignite combustion causes the highest levels of greenhouse gas emissions. In order to reach the emission reduction goals, the government launched the process of accelerating the reduction of coal consumption. On 2 July, the Federal Ministry for Economic Affairs and Energy published a plan to reform the German energy market which will be implemented during the present term of government. Emission reduction from coal power plants is the most important issue. This problem has been extensively discussed over the past year and has transformed into a conflict between the government and the coal lobby. The dispute reached its peak when lignite miners took to the streets in Berlin. As the government admits, in order to reach the long-term emission reduction objectives, it is necessary to completely liquidate the coal energy industry in Germany. This is expected to take place within 25 to 30 years. However, since the decision to decommission nuclear power plants was passed, the German ecological movement and the Green Party have shifted their attention to coal power plants, demanding that these be decommissioned by 2030 at the latest.

Gas demand for power generation peaked as early as 2010. CEPS Commentary, 12 February 2016

The outlook for natural gas demand is often considered bright, especially for gas used to generate electricity. This is because gas is the cleanest of all fossil fuels. The carbon intensity of modern gas-fired power stations is less than 50% that of modern coal plants. Moreover, gas-fired units are well-suited to follow rapid swings in supply and demand due to their flexibility. In the future, these balancing tasks will become more and more important given the intermittent character of the supply of wind and solar power. Gas seems to hold out the promise of being a key pillar of the energy transition and the perfect partner of renewables. Given the EU’s long-term climate policy goals, however, there is strong evidence that demand for gas for purposes of power generation peaked as early as 2010.

Choice receipts : arranged for the gas stove /

Includes index.

Ecological studies of fish near a coal-fired generating station and related laboratory studies : Wisconsin power plant impact study /

"Grant no. R803971."

Federal and Indian lands coal, phosphate, potash, sodium, and other mineral production, royalty income, and related statistics.

Fiscal year coverage, 1971-1975; calendar year coverage, 1976-1980.

Gas industry.

Title from cover.

Siting new coal-fired power plants in Illinois : a guide to permits and economic incentives /

Summary: On June 22, 2001, the groundwork was laid for the construction of new electric generation in the state of Illinois when the Illinois Resource Development and Energy Act was signed. Overwhelmingly approved by the Illinois General Assembly, this broad-based $3.5 billion package is designed to reinvigorate the Illinois coal industry and to strengthen the state's ability to provide electricity to its citizens. The legislation (Public Act 92-0012) provides tax incentives and financial assistance to builders of new electric plants generating in excess of 400 megawatts that create Illinois coal-mining jobs, new and expanding coal mines, and natural gas-fired baseload electric plants with a capacity of 1,000 megawatts. The legislation also directs the the Illinois Environmental Protection Agency to explore the need for a state-level, multi-pollutant strategy to reduce emissions from coal-fired electric generating plants.

Gas world.

Coal abstracts

Carbonisation of coal in continuous vertical retorts:

Mode of access: Internet.