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Journal of Combustion
Volume 2012, Article ID 495894, 7 pages
Research Article

Dairy Biomass-Wyoming Coal Blends Fixed Gasification Using Air-Steam for Partial Oxidation

1Department of Mechanical Engineering, University of the Andes, Carrera 1 Este No. 19A-40, Office ML 652, Bogotá, Colombia
2Department of Mechanical Engineering, Texas A&M University, 307 Mechanical Engineering Office Building, College Station, TX 77843, USA

Received 29 June 2011; Revised 8 November 2011; Accepted 30 November 2011

Academic Editor: Claes Tullin

Copyright © 2012 Gerardo Gordillo and Kalyan Annamalai. This is an open access article distributed under the Creative Commons Attribution License, which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properly cited.


Concentrated animal feeding operations such as dairies produce a large amount of manure, termed as dairy biomass (DB), which could serve as renewable feedstock for thermal gasification. DB is a low-quality fuel compared to fossil fuels, and hence the product gases have lower heat content; however, the quality of gases can be improved by blending with coals. This paper deals with air-steam fixed-bed counterflow gasification of dairy biomass-Wyoming coal blend (DBWC). The effects of equivalence ratio (1.6<Φ<6.4) and steam-to-fuel ratio (0.4<𝑆𝐹<0.8) on peak temperatures, gas composition, gross heating value of the products, and energy recovery are presented. According to experimental results, increasing Φ and (𝑆𝐹) ratios decreases the peak temperature and increases the H2 and CO2 production, while CO production decreases. On the other hand, the concentrations of CH4 and C2H6 were lower compared to those of other gases and almost not affected by Φ.

1. Introduction

There is a growing interest in the development of alternatives to fossil fuel technologies in order to reduce both the dependence on fossil fuels (crude oil, coal, and natural gas) and the emissions generated by their wide spread usage. The conversion technology based on gasification has the advantages of being almost fuel independent compared to digestion and fermentation processes along with reduced grinding costs compared to suspension fired approach. Biomass fuels (e.g., energy crops, agricultural and forestry residues, and municipal, industrial, and animal wastes) can serve as a renewable feedstock for thermal gasification processes to produce gaseous fuels, which can be used for on situ clean power generation, since biomass is a neutral carbon fuel. Alternatively, by using catalysis or biocatalysis processes, the gaseous fuels produced could be converted to chemicals and liquid fuels.

Air gasification processes for coal and wood have been used for a long time to produce gaseous fuels for heat or power generation through internal combustion engines; however, only recently fundamental thermal gasification studies have been performed in order to improve the quality of the gaseous fuels produced. The quality (composition and heating value) of the product gases depends mainly on the type of fuel fed to the reactor, size of the reactor, and oxidizer used in the process as well as on the flow rates of both fuel and oxidizer via air and steam supplied simultaneously to the reactor. The most relevant gasifiers developed around the world have been fixed bed (updraft and downdraft), fluidized bed, and entrained flow [1, 2]. The main difference of those reactors is the path followed by both the biomass and oxidizer within the reactor. This path affects both the resulting gas composition and the temperature profile along the reactor axis. The temperature profile is almost constant in the air blown gasifiers (fluidized bed and entrained flow) but presents a peak, which indicate the combustion region, in the fixed-bed gasifiers. The gas temperature leaving air blown down draft gasifiers is higher than that leaving a fixed-bed counterflow gasifier; therefore, the energy recovery efficiency within the bed for the fixed-bed updraft gasifiers is typically higher.

Gasification of biomass with steam (e.g., steam reforming) is used to produce H2 enriched mixtures of CO2; however, this is an endothermic process which requires an external heat input, leading to lower gasification efficiencies. On the other hand, gasification of biomass with air-steam also produces mixtures rich in H2, but, in theory, this process can be carried out without additional heating, which implies higher efficiencies. Gasification with only air produces mixtures rich in CO.

The main components of the gaseous fuel that result from gasification processes are CO, CH4, CO2, H2O, H2, N2, and trace amounts of light hydrocarbons in proportions that depend on many operating parameters. The main stages in gasification are drying, pyrolysis, partial oxidation, and reforming. They occur in all locations within the fluidized- and entrained-bed gasifiers, but they are separated in four different zones in fixed-bed gasifiers providing means for better control and process selectivity. Concentrated animal feeding operations (CAFOs) such as cattle feedlots and dairies produce a large amount of manure, cattle biomass (CB), and dairy biomass (DB) which may lead to land, water, and air pollution if waste handling systems for storage and treatment are not properly managed. It is estimated that, at any given time, there can be over 10 million of cattle heads present in feedlots in the United States [3], which could produce over 365 million of wet tons of manure per year since each animal can excrete about 27 kg of feedlot manure or feedlot biomass (FB) (including moisture) per day [4]. Full-grown milking cows can produce 7 to 8% of their body weight in manure per day that is, roughly 7.3 dry kg per animal per day. About 24 billion dry kg (26.7 million tons) of dairy manure is produced per year in the US [5]. If thermal gasification technology is developed for DB fuels, the environmental impact from both animal feeding operations and fossil fuels could be mitigated. DB which has high ash content (14.95%) and low heating value (12844 kJ/kg as received basis) is a low-quality fuel compared to fossil fuels such as coal (~21385 kJ/kg as received basis) and natural gas (~50000 kJ/kg); however, the quality can be improved by blending with coals.

Some previous studies have focused on fixed-bed cattle biomass gasification using different operating conditions and various oxidizing sources. In 1980, Raman et al. [6] presented experimental results on fluidized-bed gasification of feedlot biomass (FB) using gases (H2O, O2, and CO2) produced by combustion of propane as oxidizing source. The effects of gasification temperature on yield, gas composition, and energy recovery were discussed. In 2005, Priyadarsan et al. [7] presented experimental results on adiabatic fixed-bed gasification of feedlot biomass (FB) and Wyoming coal–feedlot biomass blends using air for partial oxidation. Two different particle sizes and two air flows were tested under non-steady-state conditions of the bed since ash is not removed from the bed. In 2009, Gordillo et al. [8] presented results from equilibrium and atom balance modeling studies on dairy biomass (DB) and feedlot biomass (FB) gasification using air-steam for partial oxidation. They [8] defined modified equivalence ratio, ERM, as the ratio of stoichiometric oxygen mass to the total actual oxygen input from both air and steam; the ERM is different from the conventional equivalence ratio (Φ) since Φ includes the oxygen input only from air. The effects of both ERM and Φ on temperature profile, gas composition (CO, CO2, H2, N2, CH4, and C2H6), gross or higher heating value (HHV), and energy conversion efficiency were discussed. Subsequently, experimental results were presented for adiabatic fixed-bed gasification of pure DB using air and steam as oxidizing source and under steady state conditions [9, 10].

It is concluded from the literature review that there is no previous work on fixed-bed gasification of DB-WYC blends and their effects on enhancement of gross heat value of product gases which include a fraction of volatile matter (VM) as released and the gases produced as a result of exothermic and endothermic reactions of VM with other species, CO and CO2, produced as result of char oxidation, and H2. The higher the HHV of VM, the higher the heat value of product species. Particularly the heat value of VM from coal is higher than that of VM from DB. Thus, the product gases from coal-DB blend are expected to have higher quality of gases. The current paper deals with gasification of dairy biomass-Wyoming coal blend (DBWC) using air-steam mixtures as oxidizing source and a small-scale (10 kW) fixed-bed updraft gasifier. Experimental results on temperature profile, gas composition of species such as CO, CO2, H2, CH4, and C2H6, and higher heat values (HHV) are presented and compared with results from pure DB in order to validate the proposed hypothesis of the enhanced quality of product gases. A mass spectrometer was used to analyze gas composition at real time and continuously. The HHV of the product gases and the energy conversion efficiency (ECE) are also presented. The conventional equivalence ratio (Φ) is defined as the ratio of the stoichiometric oxygen moles to actual oxygen moles while the steam-to-fuel ratio (S : F) is defined as the ratio of moles of steam-to-fuel moles (1):Φ=Stoichiometricairmoles=actualairmolesStoichiometricO2molesactualO2=𝑎moles𝑒,𝑆𝐹=kmolofsteamkmolofempiricalDAFfuel=𝑓,(1) where 𝑎 corresponds to the moles the oxygen required for complete combustion of an empirical fuel mole and 𝑒 and 𝑓 the oxygen moles and steam moles supplied to the gasifier for partial oxidation of an empirical fuel mole.

2. Materials and Methods

2.1. Experimental Facility

The experiments were developed using a small-scale (10 kW) gasification facility composed of a batch-type counterflow gasifier, K-type thermocouples to measure the temperature at 8 locations along the gasifier axis, an ash disposal system so that the experiments could be run continuously under steady state conditions with periodic ash disposal, a steam generator to produce the steam supplied to the gasifier, a sampling system to prepare the samples (retain tar and particulate material) to be analyzed at real time and continuously by a mass spectrometer (MS), a data acquisition system to store the temperature, and a control panel to control the flows of steam, air, and heat supplied to the heater elements placed in the steam generator and the gasifier combustion chamber. A schematic of the gasification facility was presented in a previous publication [9], and it is also available elsewhere [8]. All the experiments were carried out adiabatically and started with a preheating routine for the empty gasifier (i.e., without biomass). When the temperature at ~2 cm above the grate achieved ~800°C, biomass was added gradually to the gasifier until the bed height increased to 17 cm, at this point, the fuel port was closed and the flows of steam and air were adjusted to the desired experimental conditions. As the biomass was pyrolyzed and the char was burned, the bed height started decreased and ash accumulated. Thus, biomass was added every 10 min and in batches to maintain a constant flow rate of 1 kg/h whereas the flow rates of air (0.56–2.26 SATP m3/h) and steam (0.19–0.43 kg/h) at 100°C were changed in order to obtain the desired experimental conditions (1.6<ER<6.4 and 0.4<𝑆𝐹<0.8). The ash was disposed off continuously from the bed to the plenum using a vibrator at the bottom of the grate. This was necessary to keep both the peak temperature (𝑇peak) at the same location and constant bed height. If ash is not disposed off periodically, the peak temperature will move toward the free surface due to ash accumulation and steady state cannot be maintained [7].

It is noted that shallow bed height will lead to gases leaving at higher temperatures, thus loosing sensible heat. With increased bed height, one provides more residence time for both the solid and gas phase reactions to proceed with increased concentration of species and reduced temperature of gases leaving the bed (Figure 3). The bed height may be selected such that the temperature of gases leaving the bed is well above the saturation temperature of H2O so that enough temperature difference exists between solid and gas phases to drive off the moisture. Typically the bed height can be varied by altering the feed rates of fuel and hence the thermal rating of the bed. For the current problem, same thermal rating is maintained at about 10 kW with constant fuel feed rate. When the gasifier achieved steady-state conditions, the temperatures were measured and stored at every 10 seconds, and the gas sampling unit was turned on to analyze continuously the gas samples by the MS during 20 minutes. The ash was analyzed to determine its composition (results on ash composition are presented elsewhere [10, 11]).

2.2. Fuel Properties

The fuel was supplied by the Texas A&M Agrilife Research and Extension Center at Amarillo, Texas. The DB-water slurry from dairies was sent to a separator where DB solids were separated from slurry, then composted and partially crushed to provide a coarse grain of 6.35 mm (1/4′′) of average particle size. The properties of the fuels were characterized by ultimate and proximate analyses on an as-received basis of pure DB and pure WYC, including heating values (HHV). The properties of DBWC blend (90% DB and 10% WYC ) were determined using the properties of pure DB and WYC and mass balance on compounds. Table 1 presents proximate and ultimate analysis of DB, WYC, and DBWC. Using ultimate and proximate analysis and atom balance on compounds, the empirical formulas for each fuel were derived as shown in Table 1. The analysis shows that (i) the HHV of DBWC (13698 kJ/kg) is higher than that of the pure DB (12844 kJ/kg), (ii) the HHV of VM for blend is higher than that of pure, DB and (iii) the FC of blend is higher that of pure DB yielding more CO.

Table 1: Ultimate and proximate analysis on an as received basis.
2.3. Experimental Conditions

Table 2 shows the experimental conditions. DBWC fuel, composed of 90% DB and 10% WYC (as received), was used as feedstock in the experiments. Dry air at 25°C and steam at 100°C were blended and supplied to the plenum of the gasifier at the flow rates required to keep Φ and 𝑆𝐹 at the desired experimental ranges which were chosen on the basis of results obtained in previous modeling studies [8]. The experiments were performed without any external heat input (almost adiabatically) and at a vacuum pressure of 39 Pa. The adiabaticity of the gasifier was verified by finding experimentally the overall heat transfer coefficient (𝑈) and determining the heat loss. Details of the experiments performed to determine 𝑈 are given in [11]. All the experiments were performed at a constant DB particulate size of ~6.35 mm. Equation (1) define the parameters investigated (Φ and 𝑆𝐹) in this study.

Table 2: Experimental conditions.

As discussed before, an MS was used to analyze CO, CH4, N2, H2, C2H6, and CO2 at real time and continuously. The MS was calibrated every 72 hours for overlapping, linearity, and sensitivity. The calibration was verified by measuring known standard mixtures. Data uncertainty in the gas composition was determined by calculation of standard deviations. Uncertainty for each gas was calculated as the ratio between the standard deviation and the average measurement. Additionally, uncertainty for temperatures was estimated as the ratio between the uncertainty of the device (±1.5°C) and the measured value. In general the uncertainty in the gases lied within ~15% and the temperature within 0.55%.

3. Results and Discussion

3.1. Temperature Profiles

Figures 1 and 2 show the results on the steady state temperature profile for 1.6<Φ<6.4 and 𝑆𝐹=0.40 and 𝑆𝐹=0.80. The results show a peak temperature near the bottom of the bed in the combustion zone where the heterogeneous reactions C+O2CO2,  C+1/2O2CO, and C+H2OCO+H2 occur. The partial and complete oxidation of char that lead to CO and CO2 production respectively, are highly exothermic reactions; thus, the heat required to drive the gasification process is self generated. Since the oxidation rate of large particles of char is almost diffusion controlled, the peak temperature (𝑇peak) depends upon the availability of O2, H2O and CO2 in the combustion zone.

Figure 1: Temperature profile along the gasifier axis for gasification of DBWC blend at 𝑆𝐹=0.4, adapted from [11].
Figure 2: Temperature profile along the gasifier axis for gasification of DBWC blend at 𝑆𝐹=0.80, adapted from [11].
Figure 3: Temperature profile along the gasifier axis for gasification of pure, DB at 𝑆𝐹=0.4, adapted from [11], also available in [10].

In general, the results show that 𝑇peak is located ~4 cm above the grate for the operating experimental conditions (𝑆𝐹=0.4 and 𝑆𝐹=0.80 and 1.6<Φ<6.4). This fixed location is possible because of the continuous ash disposal from the bed to the gasifier plenum.

The effect of Φ and 𝑆𝐹 on 𝑇peak is illustrated on Figures 1 and 2. Increasing Φ and S : F results in decreased 𝑇peak. At constant Φ, increasing S : F implies more steam entering to the gasifier; thus, the reaction C+H2OCO+H2, which is endothermic, is favored (e.g., at Φ=1.6 and 𝑆𝐹=0.4𝑇peak =1054°C whereas at Φ=1.6 and 𝑆𝐹=0.8𝑇peak=844C). At fixed 𝑆𝐹, increasing Φ implies reduced oxygen supply and hence reduced exothermic heat and peak temperature in the bed.

The temperature profile of pure DB is shown in Figure 3 for 𝑆𝐹=0.40 and 1.6<Φ<6.4. As discussed before, 𝑇peak depends mostly of steam (S : F) and O2 (Φ) concentration in the combustion region. Comparing Figures 1 and 3, it is apparent that the addition of WYC increases 𝑇peak (e.g., at Φ=1.6 the 𝑇peak of DBWC is about 30°C higher than 𝑇peak of pure DB). This could be due to the decrease of the bed porosity (void fraction) in the combustion region since the particle size of DB (6.35 mm) is higher than that of WYC (0.5 mm). This is because WYC particles, whose particle size is smaller than that of DB, lie between larger sized DB particles decreasing porosity and increasing gas velocity. Increased velocity means improving heat and mass transfer between the gases and DB particles; hence, the fuel burning rate increases per unit of volume. This causes higher heat generation in the oxidation zone, which leads to a higher temperature. Since the gasifier was fed in batches, the curves of the gas stream region lack a consistent trend; thus, the effect of the WYC addition is not clear near the bed surface.

3.2. Gas Composition

Once a steady-state condition was achieved (i.e., 𝑇peak did not change the value or location), gas samples were withdrawn from the top of the gasifier and analyzed at real time and continuously using a mass spectrometer (MS) calibrated to measure CO, CO2, H2, CH4, C2H6, N2, and O2. The gas analysis was performed at steady-state condition during 20 minutes to decrease the uncertainty of results, which results in an average uncertainty of value of ~15%. The results on gas composition discussed in this paper correspond to the average measured during the last ten minutes of each experiment. For all the experiments the gas analysis did not show presence of O2. Figures 4 and 5 show the mole percentage (dry basis) of H2, CO2, CO, CH4, C2H6 for 𝑆𝐹=0.4 and 𝑆𝐹=0.80 and various equivalence ratios (Φ).

Figure 4: Gas composition of DBWC gasification at 𝑆𝐹=0.40 and several Φ (figure adapted from [11]).
Figure 5: Gas composition of DBWC gasification at 𝑆𝐹=0.80 and several Φs, adapted from [11].

From the results, it is apparent that, at constant S : F, increasing Φ results in an increase in the H2 and CO2 productions but CO concentrations are lower. Increasing Φ decreases 𝑇peak in the combustion zone where the reactions C+O2CO2 and C+1/2O2CO occur, which results in favored conversion to CO2 with consequent low CO concentrations [12]. Also, at constant S : F, increased Φ implies less oxygen entering to the gasifier with the air, and hence the fuel oxidation process occurs in an ambient rich in H2O which favors the reaction C+H2OCO+H2. However, the CO produced by this reaction is consumed by the water-gas shift reaction (CO+H2OH2+CO2) to produce more CO2  and H2.

Figure 5 shows that increased 𝑆𝐹 at constant Φ increases the production of H2 and CO2 and decreases CO. The steam supplied to the gasifier increases with increased 𝑆𝐹; therefore, there is more H2O available for the reactions C+H2OCO+H2 in the combustion zone and CO+H2OH2+CO2 in the reduction, pyrolysis, dry, and stream gas zones. Competing reactions are present for CO while CO2 and H2 have an increasing trend. The effect of the Φ and 𝑆𝐹 on the production of the hydrocarbons (CH4 and C2H6) is insignificant. On the other hand, the results show that the effect of the 𝑆𝐹 on the H2 production is more important than that of the equivalence ratio (Φ). For example, at 𝑆𝐹=0.4 and 𝑆𝐹=0.8, increasing Φ from 1.6 to 6.4 increases the CO moles by about 3% whereas increasing S : F from 0.4 to 0.8 increases the H2 production by about 7%. In general for this set of experiments, there were mixtures with CO ranging between 6.5 and 13.6% and H2 ranging between 16 and 26.3%. The CH4 and C2H6 productions ranged from 0.4 to 1.5% and 0.25 to 0.60%, respectively.

Figure 6 illustrates the effect of adding WYC to DB on CO and H2 production and 𝑇peak. Adding WYC to DB contributes to increase the HHV and void fraction of the fuel; thus, the temperature in the combustion region (𝑇peak) also increases. Increased 𝑇peak tends to increase the char oxidation rate to produce CO instead of CO2 [12]. In general, the presence of WYC increased 𝑇peak and the CO production by about 4.5% and 25% (average), respectively. The effect of adding WYC on the H2 production is important at Φ<3.6 but at Φ>3.6 it seems to be insignificant. Also, it is apparent that WYC addition affects more the CO production at Φ>3.2 than at Φ<3.2. This seems to indicate that, at Φ<3.2, the WYC addition favors the reaction rate of the shift reaction (CO+H2OCO2+H2) whereas at Φ>3.2 the effect of WYC addition on the shift reaction seems to be negligible. It could not be ascertained whether the effect on the shift reaction rate is due to temperature effect (physical) or catalytic (chemical) effect. The maximum increase in H2 production (~19%) by WYC addition was achieved at Φ=1.6.

Figure 6: Comparison between H2 and CO produced by gasification of DBWC and DB at 𝑆𝐹=0.4, curves of DB adapted from [11].
3.3. HHV of Gases

The HHV or energy density of the gases was calculated using (2). HHVgas=𝑖𝑋𝑖×HHV𝑖,(2) where 𝑋𝑖 and HHV𝑖 are mole fraction and gross heating value of species “i” (i = CO, CH4, H2, etc.) in kJ per SATP m3 of dry gaseous fuel species “i” leaving the gasifier. The HHVgas is the HHV (kJ per SATP m3) of the product gas mixture.

Table 3 presents the energy density of the gases at 1.6<Φ>6.4 and 𝑆𝐹=0.4 and 0.8, respectively. The results indicate that increased 𝑆𝐹 increases the gross heating value of the gases; this is due principally to the increase in the production of hydrocarbons and H2. At constant 𝑆𝐹, increasing Φ tends to increase the HHV until certain Φ beyond which it starts to decrease. The HHV for the selected operating conditions varied from 3649 to 4793 kJ/SATP m3. The highest HHV (4793 kJ/SATP m3) was measured at Φ=3.2 and 𝑆𝐹=0.80 whereas the lowest HHV was measured at Φ=1.6 and 𝑆𝐹=0.4. From Table 3 it is evident that the effect of 𝑆𝐹 ratio on HHV of gases is stronger than that of Φ. From Table 3, it is evident that the energy density of the product gases which results from DBWC gasification is higher than that of the gases produced from DB gasification.

Table 3: Energy density of gases on a dry basis (kJ/SATPm3) as a function of Φ and various 𝑆𝐹 ratios for DB and DBWC, adapted from [11].
3.4. Energy Conversion Efficiency

The energy conversion efficiency (ECE), or energy recovery, was calculated using yield of gases, energy density of the gases, and (3) =ECEHHVgases𝑁fuel×HHVfuel+𝑁𝑆×𝑀𝑆×𝜆+𝐶𝑝×𝑇𝑆𝑇𝑎,(3) where 𝑁fuel and 𝑁𝑠 correspond to the moles of fuel and steam supplied, respectively, to the gasifier by each SATP m3 of dry product gases, λ, latent heat of steam (kJ/kg·K), HHVfuel, gross heat value (kJ kmol−1 of DAF (dry ash free) empirical fuel), 𝑀𝑆 = molar mass of steam (kg/kmol), 𝐶𝑝, steam heat specific (kJ/kg·K), 𝑇𝑠, steam temperature, and 𝑇𝑎, ambient temperature.

Due to the impossibility of measuring the mass of tar produced during the experimentation, the yield gas, required to calculate the energy recovery, was estimated by mass balance using the compositions of tar and gases. The results on ECE are presented in Table 4 for 𝑆𝐹=0.40 and 𝑆𝐹=0.80 and several Φ. The ECE increases with increased 𝑆𝐹 ratios but decreases with increased Φ. This is due to the fact that increased Φ implies insufficient oxygen for complete oxidation of char, and hence lower amounts of combustible gases are produced and more fuel is lost through the char per fuel unit. Ultimate and proximate analyses were performed on tar to determine its composition. Details of tar content in gases, char content in ash, and tar composition (elemental composition) obtained by ultimate analysis are given in [11]. The ECE discussed in this paper ranged from 26% to 77% and is a little higher than that presented in previous works [6] for nonadiabatic fluidized bed gasification of FB (0.20–0.60). This agrees with the fact that in an updraft fixed-bed gasifier the sensible heat loss of the gases leaving the gasifier is lower than that of the gases leaving a fluidized-bed gasifier.

Table 4: Energy conversion efficiency (ECE) as a function of the Φ and various S : F ratios, adapted from [11].

4. Conclusions

(1)𝑇peak in the combustion region lies ~4 cm above the grate and decreases with increased Φ and 𝑆𝐹 ratios. Gasification of DBWC at Φ𝑠>6.4 and 𝑆𝐹>0.8 could lead to lower temperatures than that required to burn the char; thus, the process under those conditions tends to be pure pyrolysis to produce char and fuel gases with high tar content. (2)Increased Φ and 𝑆𝐹 ratios produce mixtures rich in H2 and CO2 but poor in CO. In general for the set of experiments presented here, the CO ranged from 6.5 to 13.6% and the H2 from 16 to 26.3%. (3)The addition of WYC increased 𝑇peak and CO by about 4.5% and 25%, respectively, compared to the 𝑇peak and the CO obtained from pure DB. (4)The effect of the 𝑆𝐹 ratio on HHV of the gases is more important than that of the Φ. Although, increased Φ produces gases with higher gross heating value, the energy recovery decreases with increased Φ due to higher tar and char production. (5)The quality of the product gases is higher with DB: coal blend than with the gasification of pure DB due to higher quality of VM, higher peak temperature, and more CO production for the blend.


The financial support from DOE-NREL Golden, CO, USA, is gratefully acknowledged.


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