A modeling approach to co-firing biomass/coal blends in pulverized coal utility boilers: Synergistic effects and emissions profiles

Pérez-Jeldres, Rubén; Cornejo, Pablo; Flores, Mauricio; Gordon, Alfredo L.; Garcı́a, Ximena

doi:10.1016/j.energy.2016.11.116

Cited by 49 publications

(14 citation statements)

References 37 publications

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“…Performed techno-economic studies [54][55][56] contribute to the co-combustion applicability assessment. The modeling and computational approach to various scale systems performance is more widespread [57][58][59], which contributes to the understanding of co-combustion systems' behavior and interactions.…”

Section: Introductionmentioning

confidence: 99%

Advances in Biomass Co-Combustion with Fossil Fuels in the European Context: A Review

et al. 2021

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Co-combustion of biomass-based fuels and fossil fuels in power plant boilers, utility boilers, and process furnaces is a widely acknowledged means of efficient heat and power production, offering higher power production than comparable systems with sole biomass combustion. This, in combination with CO2 and other greenhouse gases abatement and low specific cost of system retrofit to co-combustion, counts among the tangible advantages of co-combustion application. Technical and operational issues regarding the accelerated fouling, slagging, and corrosion risk, as well as optimal combustion air distribution impact on produced greenhouse gases emissions and ash properties, belong to intensely researched topics nowadays in parallel with the combustion aggregates design optimization, the advanced feed pretreatment techniques, and the co-combustion life cycle assessment. This review addresses the said topics in a systematic manner, starting with feed availability, its pretreatment, fuel properties and combustor types, followed by operational issues, greenhouse gases, and other harmful emissions trends, as well as ash properties and utilization. The body of relevant literature sources is table-wise classified according to numerous criteria pertaining to individual paper sections, providing a concise and complex insight into the research methods, analyzed systems, and obtained results. Recent advances achieved in individual studies and the discovered synergies between co-combusted fuels types and their shares in blended fuel are summed up and discussed. Actual research challenges and prospects are briefly touched on as well.

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Section: Introductionmentioning

confidence: 99%

Advances in Biomass Co-Combustion with Fossil Fuels in the European Context: A Review

et al. 2021

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“…A similar work was carried out by Stroh et al 18 in a down‐fired furnace with torrefied sawdust, but they claimed that a higher biomass substitution would cause incomplete combustion due to the larger size of biomass particles. Pérez‐Jeldres et al 19 found that a 5% biomass (pine sawdust) substitution would lead to a 5% reduction of SO 2 , 2% increase of mean temperature and 0.6% reduction of heat transfer on water tubes. More recently, a plenty of modeling works have been conducted to check the feasibility of implementing biomass co‐firing under oxy‐fuel operation toward the “zero emission” target, 20–22 while most of them were focused on the change of combustion performance under different biomass substitution ratios.…”

Section: Introductionmentioning

confidence: 99%

Effect of biomass co‐firing position on combustion and NO_X emission in a 300‐MWe coal‐fired tangential boiler

DONGFENG

et al. 2021

Asia-Pacific J Chem Eng

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Co‐firing biomass in an existing coal combustion boiler is a promising way to mitigate carbon emission in the context of global carbon neutrality. This paper investigated the effect of biomass injection location on combustion and NOX formation characteristics in a 300‐MWe tangential boiler co‐firing with coal. Numerical models have been validated against experimental measurement for both pure coal firing and biomass/coal co‐firing cases. Compared to pure coal firing, co‐firing case with biomass injected into the highest layer can sustain a comparable temperature distribution profile along the furnace height, and generate a lower NO emission by around 20 ppm. By moving the biomass injection location downward, the temperature difference between co‐firing and pure coal firing cases becomes larger, and the final NO emission increases continually from 222 to 240 ppm. When biomass is injected through the lowest layer, N element in biomass volatile is oxidized to NO directly because of the abundant oxygen; thus, NO emission turns to be the highest among all co‐firing cases. Contrarily, when biomass is injected through the highest layer, the majority of N in biomass volatile is released as NH3, and it further acts as a reduction agent for NO, thus leading to the lowest NO emission.

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“…The oxidative combustion properties of pulverized coal are the key factors affecting its combustion efficiency and emission amounts. Therefore, plenty of experimental techniques have been adopted to examine coal oxidation and combustion, including thermogravimetry, , thermal release, and combustion reaction, which have provided more detailed insights into the oxidative combustion properties of pulverized coal under a variety of oxygen-enriched atmospheres and with different particle sizes.…”

Section: Introductionmentioning

confidence: 99%

Effect of Oxygen Concentration on the Oxidative Thermodynamics and Spontaneous Combustion of Pulverized Coal

Ren

Deng

et al. 2021

ACS Omega

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Spontaneous combustion of pulverized coal has become a safety topic and has been extensively researched. This study using differential scanning calorimetry investigated the exothermic characteristics and spontaneous combustion risk of three metamorphic pulverized coal samples during oxidative combustion, for oxygen concentrations of 21, 19, 17, 15, 13, 11, 9, 7, and 5 vol %. Results indicated that decreased oxygen concentrations reduced exothermic intensity and substantially increased ignition temperatures. The oxidative thermal release observed during the combustion stage was conspicuously higher than during the low-temperature oxidation stage. Thermal release during low-temperature oxidation was low during low oxygen concentrations; however, when the oxygen concentration was less than 13.0 vol.%, it had a considerable influence on exothermic combustion. When the oxygen level was lowered from 21.0 to 5.0 vol %, spontaneous combustion risk indexes lessened from 2.07 (sample A), 1.85 (sample B), and 0.81 [J/(mg min °C2 )] (sample C) to 1.08 (sample A), 1.13 (sample B), and 0.40 [J/(mg min °C2 )] (sample C), respectively. Both apparent activation energy and spontaneous combustion risk indexes of the samples decreased saliently as oxygen concentration decreased. Thus, reducing oxygen concentration would be an effective method of inhibiting or possibly even preventing the spontaneous combustion of pulverized coal.

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A modeling approach to co-firing biomass/coal blends in pulverized coal utility boilers: Synergistic effects and emissions profiles

Cited by 49 publications

References 37 publications

Advances in Biomass Co-Combustion with Fossil Fuels in the European Context: A Review

Advances in Biomass Co-Combustion with Fossil Fuels in the European Context: A Review

Effect of biomass co‐firing position on combustion and NO_X emission in a 300‐MWe coal‐fired tangential boiler

Effect of Oxygen Concentration on the Oxidative Thermodynamics and Spontaneous Combustion of Pulverized Coal

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A modeling approach to co-firing biomass/coal blends in pulverized coal utility boilers: Synergistic effects and emissions profiles

Cited by 49 publications

References 37 publications

Advances in Biomass Co-Combustion with Fossil Fuels in the European Context: A Review

Advances in Biomass Co-Combustion with Fossil Fuels in the European Context: A Review

Effect of biomass co‐firing position on combustion and NOX emission in a 300‐MWe coal‐fired tangential boiler

Effect of Oxygen Concentration on the Oxidative Thermodynamics and Spontaneous Combustion of Pulverized Coal

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Effect of biomass co‐firing position on combustion and NO_X emission in a 300‐MWe coal‐fired tangential boiler