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66 VGB PowerTech 4/2008
CHP with Biomass Gasification and MGT
Kurzfassung
Integrierte Wärme- und Strom-erzeugung mit Biomassevergasung
und SOFC-Mikrogasturbine
Autotherme Biomassevergasung erfordert kei-
ne externe Wärmezufuhr, da diese mit Luft als
Vergasungsmittel betrieben wird, und produ-
ziert einen gasförmigen Brennstoff (Synthese-
gas), der gereinigt und konditioniert wird und
anschließend in eine oxidkeramischen Brenn-
stoffzelle (SOFC) genutzt werden kann. Vom
Konzept her kann das integrierte System unter
atmosphärischem oder unter etwas erhöhtem
Druck betrieben werden, und ermöglicht so
die Kombination mit einer Mikrogasturbine
(MGT). In dem vorliegenden Beitrag werden
drei kleine Kraft-Wärme-Kopplungssystme
(KWK) miteinander verglichen, die diese Tech-
nologien integrieren: a) Vergasung unter 4 bar
plus MGT, b) Vergasung unter 1,4 bar plus
SOFC und c) Vergasung unter 4 bar plus
SOFC-MGT. Jedes Haupt- und Zusatzbe-
standteil des KWK wurde mit Hilfe der As-
penplus™-Prozeßsimulationssoftware simu-
liert. Das interessanteste Ergebnis war, dass
sich das MGT-System gegenüber dem atmos-
phärischen System mit SOFC als effizienteres
herausgestellt hat. Beide Systeme wurden je-
doch durch die Leistung des kombinierten
SOFC-MGT-Systems übertroffen, das eine
exergetische elektrische Leistungsfähigkeit
von 35,6 % aufweist, mit einer aktiven SOFC-
Fläche von 100 m2 und einen nominalen Bio-
massedurchsatz von 200 kg/h. Die angewand-
te Exergieanalyse erlaubte die Optimierung
des SOFC-Brennstoff-Anwendungsfaktors (Uf)
und die Ermittlung der Auswirkung der Pro-
duktgaseanfeuchtung vor der Brennstoffzelle,
auf das Niveau der Leistungsfähigkeit und Ka-
pazität des Systems.
Introduction
There is an increasing trend to develop moreefficient biomass-fuelled energy systems.Steam cycles driven by biomass combustionin the range of 5 to 20 MWe currently pro-duce most of the bioelectricity worldwidewith electrical efficiencies around 20 %. Sol-id biofuel gasification was recently estab-lished as a significant option for power plantsbased on combined cycles that can achieveefficiencies of above 35 % in the ranges of20 to 40 MWe [1, 2]. In parallel, R&Dmoved towards efficient, small-scale CHPsystems incorporating gasification and use ofproduct gas in internal combustion engines,micro gas turbines or fuel cells. More specifi-cally there is a growing interest and promis-ing works on the combination of biomassgasification and Solid Oxide Fuel Cells(SOFCs) [3 to 6], mainly because these canutilise the product gas CO content and haveinherent higher tolerances towards severalproduct gas contaminants compared to otherfuel cell types.
The paper at hand presents an investigationon the combination of an air-blown fluidisedbed biomass gasifier with a high-temperatureSOFC and/or MGT in a CHP system of lessthan 1 MWe, which could respectively oper-ate at two pressure levels, near atmosphericand ~ 4 bar. The analysis is based on realisticperformance estimations by taking into ac-count the functionality of the proposed con-figurations without overestimations or grossassumptions. For this purpose, accurate mod-els were incorporated into the AspenplusTM
process simulation software for all the inte-grated unit operations, followed by an exer-getic analysis; second law efficiencies for themajor process steps and for the overall CHPsystem were evaluated and discussed, en-couraging comparisons with existing exer-getic analyses on biomass gasification [7]and SOFCs [8 to 14].
System Description and Modelling Aspects
Three possible configurations for a Com-
bined Heat and Power (CHP) system areshown in F i g u r e 1 , incorporating a flu-idised bed air-blown gasifier, a warm gascleaning train, an SOFC stack and its powerconditioning, and/or an MGT. These are:
a) near atmospheric gasification plus SOFC,
b)pressurised gasification (at 4 bar) plusSOFC-MGT,
c) pressurised gasification (at 4 bar) and MGT.
The peripheral unit operations include twoair compressors/blowers allowing flexibilityof operation of the gasifier and SOFC, gas-to-gas heat exchangers (HX 1, 2 and 3), aheat recovery steam generator (HRSG –HX4) producing saturated steam at around418 K, and (HX5) to make use of the flue gasthermal content. Olive kernel was consideredas the biomass fuel for the gasifier. Particu-lates are removed from the hot raw productby a ceramic filter while downstream tar re-moval takes place in a fixed catalytic bed. Tofacilitate halogen and sulphide removal insorbent beds, the gas is cooled down toaround 430 K [15]. Heat losses during gascleaning were accounted as 30 % losses fromthe heat transferred across HX1, in which theclean gas is reheated up to 900 K with thehelp of the hot product gas. For trouble-freeSOFC operation without carbon deposition,steam is added to increase the steam to car-bon ratio (STCR) of the product gas. SOFCair is preheated up to some 880 K by fluegas heat exchanger HX2. In the MGT option,HX2 serves as the recuperator air preheater.Depleted fuel and air from the SOFC react inthe post-cell combustion chamber providingheat for further cathode air preheating up to900 K. If the SOFC operates at increasedpressure, it is followed by an MGT expander,which produces additional power and coversthe compressor work demand. In the atmos-pheric operation an additional flue gas heatexchanger HX3 is employed to preheat airfor the gasifier; in the pressurised options airis preheated only through its compression.Flue gas HX4 provides saturated steamwhich is added to the product gas for its hu-midification before the SOFC stack. HX5produces useful heat through a heat transfermedium at the available off gas temperatureminus the minimum allowed �T across theheat exchanger. The SOFC system is basedon the existing tubular concept by Siemens-Westinghouse [16], with a 100 m2 active sur-face and nominal power output in the rangeof 200 to 250 kWe.
Dr. Mech.-Eng. Lydia Emilie Fryda*
Energy Research Centre of the Netherlands (ECN), Petten/The Netherlands
Dr.-Ing. Kyriakos D. Panopoulos
Laboratory of Steam Boilers and ThermalPlants, School of Mechanical Engineering,Thermal Engineering Section, National Technical University of Athens,Athens/Greece
Professor Dr.-Ing. Emmanuel Kakaras
Laboratory of Steam Boilers and ThermalPlants, School of Mechanical Engineering,Thermal Engineering Section, National Technical University of Athens, Athens/Greece
AutoorsAuthors
Integrated Combined Heat and Power with BiomassGasification and SOFC-micro Gas Turbine
* Dr. Fryda was awarded the Heinrich-Mandel-Prize 2007 for her work on the utilisation of biomass in decentral generation stations <1 MW with fluidised bed combustion systemsand the application of oxide-ceramic fuel cells.
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VGB PowerTech 4/2008 67
CHP with Biomass Gasification and MGT
Steady state flow sheet models of the threeconfigurations were developed in Aspen-plusTM process simulation software togetherwith special FORTRAN blocks for the mod-elling of gasifier and SOFC sections. TheRedlich-Kwong-Soave cubic equation of statewas employed for the gas properties estima-tion [17]. The pressure drop across each unitoperation was assumed 1%. Heat exchangerswere allowed a significant minimum temper-ature difference of �T > 50 K in countercur-rent mode. This is a rather conservative as-sumption if higher efficiencies are demandedbut further reducing �Ts would result incostly heat exchangers. Heat losses in thegasifier, the HRSG and the heat exchangerswere assumed ≥ 2 % of the heat transferred.
Methodology for the Exergetic Analysis
Steady state flow sheet results were used toperform an exergy analysis on each sub-process, i.e. work potential of material andheat streams at any point in a series of energyconversion devices were evaluated in exergyterms. Exergy is the maximum possibleamount of work that can be obtained from amaterial or heat stream that eventually equili-
brates with the reference environment, whichconsists of reference components and is char-acterised by absence of pressure and temper-ature gradients.
The exergy of a material stream is given asthe sum of molar physical and chemical exer-gy:
E = N (�ph + �ch) (W) (1)
The molar physical exergy of a materialstream is evaluated using the data on physicalproperties, temperature (T), pressure (p),enthalpy (h) and entropy (s), calculated byAspenplusTM and its properties in referenceenvironmental conditions (To = 298.15 K,po = 1.013 bar) using the following expres-sion:
�ph = (h – ho) – To (s – so) (J mol-1) (2)
The molar chemical exergy is obtained whenthe components of the energy carrier are con-verted to reference compounds and diffuseinto the environment:
�ch = ��i�oi + RTo��i ln �i (J mol-1) (3)i i
where �i is the mole fraction and �oi is thestandard molar chemical exergy (J mol-1) ofeach component i, assuming a reference at-mospheric composition given by Kotas [18].
The chemical exergy of the solid fuel wascalculated 17689 kJ kg-1 with the help of the statistical correlation �, proposed bySzargut [19]:
�ch, fuel = (LHVfuel, dry + whfg) � + (�o
s – Huso zs (kJ kg-1) (4)
T a b l e 1 presents the proximate and ulti-mate analysis of the biomass fuel (dried olivekernel). The oxygen to carbon mass fractionof the solid fuel is calculated between 0.667≤ (zO2 / zc) ≤ 2.67, and the formula for woodis applied [19], which gives � =1.1182.
The exergy of a heat stream Q is given with the help of the Carnot factor: EQ
T =Q (1 – To / T), where T is the temperature at which Q is available. Exergy of power output, EW, equals power itself.
AspenPlusTM flow sheet calculations providevalues for mole flows N and mole fractions�i of all streams, as well as their physicalproperties (h, s, T, �). The evaluation of themolar reference enthalpy and entropy (ho, so)of every material stream was obtained bya duplicate of each stream expanded andcooled to reference conditions.
For the modeling of a realistic system, heat losses were introduced in several unit operations. These losses do not increase the
HCl, H2Sremoval
FB biomassgasifier 1080 K
Particulate filter
Char/Ash
Clean Product gas
900 K
CV 1
HX1
Biomass
Catalytic tardestruction
Flue gas outlet 363 K
SOFC 1173K
A C Inverter
Power
Flue gas to expander
1173 K
Post
combustor
Hot air 900K
Flue gas ~ 850 K
HX2 HX5
Usefulheat
Hot air 880 K
CV 2
Combustor
HX3
MGT option
Hot air
480 K
Atmosph. SOFC option
Air 293 K
Hot air 880 K
G
SOFCoptions
Pressurisedoptions
SOFCoptions
Atmosph.SOFCoption
SOFCoption
HX4
Water
Saturated steam
418 K
Air
Biomass/syngas
H2O
Flue gas
TIT temperature
Control air
CV 3
CV 4
Heatlosses
Figure 1. Flow sheet diagram of the biomass gasification CHP with SOFC and/or MGT.
066-074_PT4_08.qxd 15.04.2008 12:00 Uhr Seite 67
68 VGB PowerTech 4/2008
CHP with Biomass Gasification and MGT
streams' entropy but contribute to exergy lossout of the system. Additionally, exergy lossesdue to mechanical and electrical inefficien-cies were considered; these deteriorate poweroutputs from equipment such as turboma-chinery and the inverter. Non-ideal condi-tions and real gas equations were used for thesimulation of each unit operation and exergylosses due to mixing were accounted; thesecannot be avoided and contribute to entropyincrease and therefore exergy destructionwithin the boundary of the system due to dis-sipation (irreversible exergy destruction).Both exergy losses and exergy destructionhave been summed up under the term 'irre-versibilities' IR, and an exergy balance for acontrol volume is expressed:
�Ej + �EQT = �Ek + �EQ
T, useful +IN IN OUT
+ �EW + IR (W) (5)OUT
Modelling of the Combined Heat and Power System
Model l ing Biomass Air Gasi f ica t ion
The Gibbs free energy minimisation methodfor the C-H-O atom blend of the biomass fueland oxidant mixture was applied for predict-ing the thermodynamic equilibrium composi-tion of product gas major components: H2,CO, CH4, CO2, H2O, N2, as well as char,which was considered as solid graphite (Cs).This thermodynamic calculation underesti-mates methane and unreacted char amountsin biomass gasification [1]. Therefore, non-equilibrium corrections were taken into ac-count to bring these product componentscloser to experimentally derived values. Theunreacted char was assumed to consist onlyof carbon and to be 5 % of the total fuel car-bon content [20], and this amount did notparticipate in the thermodynamic equilibriumcalculations. In a similar fashion, CH4 con-tent (mainly deriving from the decomposi-tion/pyrolysis of biomass) was assumed toreach 4 % v/v in the final nitrogen-free prod-uct gas [21].
The oxidising agent throughput determinesthe gasifier operating temperature. In order toachieve autothermal gasifier operation at adesired temperature, the air input was adjust-ed with a FORTRAN calculator allowing2 % heat loss. The air ratio with respect to
the gasifier fuel input is expressed consider-ing the amount required for stoichiometriccombustion of the fuel, as Equivalence Ratio
Air input (kg s-1)ER = –––––––––––––––––––––
Stoichiometric air (kg s-1) (6)
The gasification cold gas efficiency neglectsthe sensible heat of the gas and char pro-duced and is defined as [1]:
LHV in cold product gascg = –––––––––––––––––––––
LHV in feedstock (7)
In order to evaluate the degree of biomasswork potential conservation in the gaseousproduct fuel, exergy analysis of air gasifica-tion is applied for the control volume 1 (CV1) shown in Figure 1. Based on the generaldefinition of the degree of perfection for aprocess by Szargut [19], the exergetic effi-ciency of air gasification is:
Egas + Echarex, gas = –––––––––––––––––––––
Ebiomass + EOT + Eair (8)
Here Egas includes the product gas sensibleheat. The gasifier operates autothermally,therefore EO
T is zero. Since in this applicationthe physical and chemical exergy of char isof no use it was not included in the nomina-tor of equation (8).
Mode l l i ng t he SOFC
The SOFC configuration and its control vol-ume are depicted in Figure 1 (CV 2). A typi-cal tubular cathode supported SOFC similarto the Siemens Westinghouse system [16]was modelled. Both anode and cathode de-pleted fuel and air are assumed to exit theSOFC stack compartment at 1173 K and areintroduced to the post-cell combustor whichserves as a final air pre-heater. The flue gastemperature could increase significantly, butfor their use in an MGT expander furtheramount of compressed preheated air is intro-duced to suppress the turbine inlet tempera-ture (TIT) to its maximum allowed value, as-sumed 1173 K.
Two operation pressure levels were studiedcorresponding to the two gasifier operationpressure levels taking into account pressurelosses, i.e. pSOFC = 1.2 bar and 3.56 bar. Dueto very low methane and hydrocarbons con-centrations in the clean product gas, the com-mon internal pre-reformer was not employedhere [22]. Also contrary to natural gas fuelledSOFC configurations [23], no recirculation
of depleted anode gas is considered, due tohigh nitrogen content of the fuel gas thatwould significantly dilute the anode gas.Supplementary steam is added to the productgas before it reaches the catalytic SOFC an-ode, to ensure carbon deposition-free opera-tion. In the base case calculations, the addi-tional quantity of steam is specified toachieve a Steam to Carbon Ratio (STCR)equal to 2:
nH2OSTCR = –––––––––––––––– (9)
nCH4 + nCO + nCO2
Nevertheless the requirement for largeamounts of steam raises two problems: findingavailable water quantities and coping with ef-ficiency penalty deriving from exergy destruc-tion associated with steam production. Thelevel of the latter negative effect was investi-gated by setting STCR as a parameter rangingfrom 0.5 (which is the least thermodynamicrequirement to avoid carbon deposition) up tothe value of 2. Similarly high STCR valueshave been suggested when partially pre-re-formed methane is fed to SOFCs to assure nocarbon deposition will occur [23, 24].
The SOFC model was built in AspenplusTM
using available blocks and a calculator with aFORTRAN routine for the electrochemicalproperties estimation. The electrochemically-reacted oxygen is separated from the cathodeand fed to the anode, which is modelled byan RGIBBS reactor model that brings the an-ode mixture into chemical equilibrium. Thelow methane content justifies this equilibri-um assumption rather than using somemethane reforming rate reactions. The fuelutilisation factor of the stack is:
nH2,REACTUf = –––––––––––––––– (10)
nINN2 + nIN
CO + 4 · n INCH4
where n iIN refers to the anode's fuel species
input and nH2,REACT is the H2 (mol s-1) react-ing in the hydrogen electrochemical reaction,which was solely considered:
H2 + (1/2) O2 ↔ H2O (11)
The output voltage of the cell is:
V = VOC – VOHM – VACT – VPO (V) (12)
The Nernst open circuit cell voltage VOC wasevaluated at a corrected average operatingtemperature TSOFC, i.e. the average betweenthe mixed anode and cathode inlet flow (~ 900 K) and the outlet of the SOFC at 1173 K:
ΔGO R · TSOFC pH2out · (pO2
out)12
VOC = –––– + –––––––– · ln ––––––– (13)2 · F 2 · F pH2O
out
where F = 6.023�1023 �1.602�10-19 Cmol-1
is the Faraday constant, 2 is the number of e- produced per H2 mole that reactsthrough reaction (11) of which the molarGibbs free energy change is expressed as
Proximate analysis Ultimate analysis (%w/w dry basis)
Volatiles (%w/w dry) 72.64 C 51.19
Fixed carbon (%w/w dry) 24.78 H 6.06
Moisture (%w/w) 10.0 O 39.32
Heating values N 0.76
HHV (kJ/kg dry) 18 900 S 0.09
LHV 15 567 Ash 2.58
Table 1. Biomass fuel data.
066-074_PT4_08.qxd 15.04.2008 12:00 Uhr Seite 68
VGB PowerTech 4/2008 69
ΔGo
= ΔHo
– TSOFCΔSo
, calculated at TSOFC
and standard pressure. Finally, pouti are the
SOFC-exit partial pressures of the participat-ing components in reaction (11). Using theabove partial pressures and temperature data,a FORTRAN calculator was used for the esti-mation of the overpotentials due to Ohmic(VOHM), activation (VACT), and polarisation(VPO) losses. This calculator, the details of which were presented elsewhere [14], isbased on works from Campanari et al.[24, 25], Chan et al. [26, 27], Costamagna etal. [23], and Selimovic [28].
The SOFC stack's power output is:
PSOFC = V · I (W) (14)
where the current is evaluated as I =2FnH2,REACT. The corresponding current den-sity is J = I /ASOFC (Am-2) where ASOFC is theactive cell surface area (m-2).
By specifying the utilisation factor, the anodeflow throughput and composition, iterativecalculations of the overall energy balance areperformed over the SOFC stack control vol-ume to result in the air throughput adjustmentto reach an almost adiabatic operation (al-lowing ~ 5 kWth thermal losses) at the de-sired SOFC temperature. The electrical effi-ciency of the stack is:
PSOFCSOFC = –––––––––––––––––––––––––––––––– (15)
n INCH4
·LHVCH4 + nINH2 · LHVH2 + n IN
CO· LHVCO
where n iN
is the molar input of each gas com-ponent and LHVi their respective lower heat-ing value, while the exergetic electrical effi-ciency [19] is:
PSOFCex,SOFC = –––––––––– (16)
Egas + Eair
Mode l l i ng o f Hea t Exchange r s andMic ro Gas Tu rb ine
Heat exchangers were modelled with As-penplusTM HEATER modules. The microgas turbine was modelled as an expander us-ing common values for the maximum tur-bine inlet temperature and an isentropic effi-ciency value of 84 %. Mechanical efficien-cies were also taken into account. T a b l e 2shows the input data for all the peripheralequipments, including the power condition-ing inverter.
Results and Discussion
Gas i f i e r Ana ly s i s Resu l t s
F i g u r e 2 a shows the calculated Equiva-lence Ratio (ER) and the cold gas efficiencyof air gasification vs. gasification tempera-ture. The two gasification pressure levelsconsidered were 1.4 bar and 4 bar. It must benoted that for both operating pressure optionsthe air inlet temperatures are equal, approxi-
0
10
20
30
40
50
60
70
80
90
100
850 900 950 1000 1050 1100 1150 1200 12500.0
0.2
0.4
0.6
0.8
pressurisedatmospheric
ηcg
ER
ER
ηcg
in %
Tgas in K
0
5
10
15
20
25
30
vol i
n %
(dry
& N
2 fre
e)
850 900 950 1000 1050 1100 1150 1200 12500
20
40
60
80
100
Gasifier operating point
CO2
CH4
H2
CO
pressurisedatmospheric
ηex, gas
ηex
, gas
in %
Tgas in K
Figure 2. (a) cold gas efficiency (%) and equivalence ratio (ER) of product gas, and (b) hot moist gas composition (% vol dry & N2 free) and pro-duct gas exergetic efficiency, for atmospheric and pressurised operation vs. gasifier temperature.
Equipment Input data
Temperatures (K) Heat losses
Heat exchangers Hot steam Cold steam % of heat
In Out In Out transfered
HX1 – – 430 900 30*
~ 940
HX2 or – – 880 2
> 1200**
HX2
HX3 hot steam – – 480 2
outlet
HX2/HX3 hot Water Steam
HX4 steam outlet – T = 293 K T = 418 2
P = 4 bar P = 4 bar
HX4 Heat transfer
HX5 hot stream 363 – medium 2
outlet at HX4 hot
stream outlet –
ΔTmin, pinch
(i.e – 50 K)
Isentropic Inlet Outlet Mechanical
Turbomachinery Efficiency temperature pressure Efficiency
(%) (K) (bar) (%)
MGT 84 1173 (max) 1.1 99.5
Air compressor/ 75 293 Downstream 98
blowers requirements
Inverter Efficiency
(%) 95
* accounting for losses through the gas cleaning system
** atmospheric cases (i.e. no MGT), temperature varies on Uf.
Table 2. Input data for peripheral equipment.
CHP with Biomass Gasification and MGT
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CHP with Biomass Gasification and MGT
mately 480 K. After the conversion of avail-able char, the gasification model results in al-most similar product gas composition forboth pressures ( F i g u r e 2 b ). There is al-ways some methane left even at higher tem-peratures and ERs because of methane cor-rection. From a thermodynamic point ofview, biomass air gasification processesshould be accomplished with the minimumair (ER) necessary above the requirement tomaximise carbon conversion. Increasing thegasifier temperature and therefore ER has anoverall negative effect on the exergetic effi-ciency because major chemical exergy carriercomponents, i.e. combustibles in the productgas, are minimised (Figure 2b). Nevertheless,kinetic reasons such as advancement of tarreforming reactions, fluidisation limitationsor heat losses might impose higher ER valuesin practice. The gasifier temperature waschosen 1080 K, and the corresponding ERvalue in both atmospheric and pressurisedmode of operation is 0.37. The model pre-dicts a very slight exergetic effectiveness in-crease in the case of pressurised gasification.
A higher moisture fuel would result in apenalty on the gasification efficiency becauseof dilution of the product gas with watervapour and requirements of higher ERs tosustain autothermal operation.
SOFC Ana ly s i s Resu l t s
The clean product gas main composition atboth pressure levels, before and after humidi-fication up to STCR = 2, are shown inT a b l e 3 . For these anode gas composi-tions, several characteristic curves are drawnfor TSOFC = 1173 K and pSOFC = 1.2 bar/3.56bar, respectively. Pressurised operation is im-proved over atmospheric, for a given fuelthroughput and utilisation factor, because (a)slightly increased current densities areachieved, (b) the SOFC voltage (V) is in-creased due to increased open circuit voltage(Voc), (c) activation overpotential is lesswhile (d) ohmic and cathode overpotentialsremain almost constant. F i g u r e 3 showsthe cell power output vs. current density forthree fuel utilisation ratios and the two pres-sure levels. SOFC power is increased forsmall Uf values because the partial pressuresof the reactants remain high until exitingthe stack. The 100 m2 SOFC stack, fed withproduct gas from the gasifier with biomassthroughput of 200 kg/h, operates with currentdensities J around 4000 A/m2; this region ofoperation was chosen for the rest of the cal-culations.
For finalising the configuration of the CHPsystem the preferred fuel utilisation has to bedetermined. The stack's air requirement (andtherefore off-gas volume) increases with Uf
because of greater cooling load required fromthe stack. Furthermore, the post-SOFC com-
bustor temperature de-creases with increas-ing Uf because theair/fuel mixture isleaner. F igu re 4shows the combustortemperature withoutadditional air, for thethree Uf values in thepressurised operationat the above-men-tioned system through-
put. Even with very high Uf = 0.85 some ad-ditional air is required to suppress the combus-tor temperature down to the maximum al-lowed turbine inlet temperature (TIT)(1173 K). Figure 4 also shows the required ad-ditional preheated air as percentage of the pri-mary SOFC air. Higher Uf (above 0.85) werenot considered because of risk of SOFC anodeoxidation. No additional air option was takeninto account in the atmospheric option whereno MGT-TIT limitation is posed.
F i g u r e 5 shows the comparison of SOFCexergetic efficiencies vs. SOFC power outputat different fuel utilisation ratios for the at-mospheric and pressurised operation. A firstremark is that SOFC stack efficiencies areconsiderably lower at atmospheric operation.Furthermore it is obvious that maximisingthe Uf does not necessarily result in higherstack efficiencies. Nevertheless this wrongassumption is very commonly taken forgranted in SOFC power cycles presentationswhich are based on gross assumptions aboutthe SOFC behaviour. Higher efficiencies aregained by lowering Uf at higher electric de-mands from an SOFC stack of a given active
surface area, and the Uf choice has to bebased on the examination of the overall CHPefficiency.
CHP Sys t em Ana ly s i s Resu l t s
After correcting the power outputs of theSOFC, PSOFC, and MGT, PGT, with mechani-cal and inverter efficiencies respectively, andsubtracting the power for compressors opera-tion, PCOMP, the energetic electrical efficien-cy of the system is defined as:
PSOFC + PGT – PCOMPel = ––––––––––––––––– (17)
(Input biomass) LHV
while the power and thermal energetic effi-ciency of the system is defined as:
PSOFC + PGT – PCOMP + QusefullCHP = ––––––––––––––––––––––––– (18)
(Input biomass) LHV
The system exergetic efficiency for electrici-ty production is:
PSOFC + PGT – PCOMPex,el = –––––––––––––––––– (19)
Ebiomass + Eair
and the combined electrical and thermal(CHP) exergetic efficiency is:
Product gas composition
(% vol)
Component Before After
steam addition steam addition
(1.4 bar/4 bar) (1.4 bar/4 bar
CH4 2.10 / 2.17 1.39 / 1.41
CO 16.80 / 18.1 11.03 / 11.76
CO2 11.16 / 10.65 7.40 / 6.95
H2 13.90 / 14.96 9.15 / 9.73
H2O 8.70 / 8.3 39.67 / 40.25
N2 47.20 / 45.7 31.33 / 29.87
Table 3. Product gas composition before and after steam addition.
Atmospheric Pressurised Pressurised
gasifier/SOFC gasifier – gasifier –
SOFC/MGT MGT
Biomass throughput
(kg/h) 200
Energetic/exergetic biomass
throughput 864 / 982
(kW)
Anode STCR 2 –
SOFC stack activa area
(m2) 100 –
Optimised Uf ~ 0.75 0.85 –
J
(A/m2) 3774 4280 –
Pnet
(kWel) 170.3 349.9 225.7
(PGT – PCOMP) / Pnet
(%) – 41.9 100
V / VOC
(Volt) 0.51 / 0.80 0.52 / 0.80 –
el / CHP
(%) 20.0 / 62.3 40.6 / 58.1 26.1 / 70.7
ex,el / ex,CHP
(%) 17.6 / 39.7 35.6 / 40.6 23.0 / 38.5
Table 4. Base case results for the three configurations studied.
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VGB PowerTech 4/2008 71
PSOFC + PGT – PCOMP + EQuseful
ex,CHP = ––––––––––––––––––––––––– (20)Ebiomass + Eair
The electrical exergetic efficiencies of thethree examined configurations for a range offuel utilisation ratios versus biomass through-put are shown in F i g u r e 6 . For a greatrange of fuel throughputs, and in specificaround the base case of 1000 kWth fuel exer-gy input (i.e. 200 kg biomass/h) the MGT op-tion has higher electrical efficiencies com-pared to the atmospheric SOFC system, de-spite its optimised Uf for that region of oper-ation (at Uf = 0.75). The atmospheric SOFCsuffers from low effectiveness to producepower together with great exergy losses asso-ciated with nil power extraction from thehigh temperature SOFC flue gases. The larg-er air compression power consumption of the
SOFC-MGT system is more than offset byincreased SOFC performance and additionalpower produced from the MGT resulting inex,el ≥ 35.6 % at biomass exergy input1000 kW. For the three systems studied andthe base case of 200 kg biomass/h, the effi-ciency ratios (i.e. equations 17 to 20) and im-portant results are presented in T a b l e 4 .The pressurised MGT configuration offersincreased thermal output but at low tempera-tures ( F i g u r e 7 c ), thus not reflected in theex,CHP.
Part of the flue gas energy of the SOFC con-figurations is consumed to produce steamfor product gas moistening, therefore, dete-riorates the quality of available heat ( F i g -u r e 7 a , b ). The influence of the requiredSTCR on the electrical and CHP system
exergetic efficiencies was studied paramet-rically. In order to present the exergy de-struction associated with steam production,two exergy loss ratios, steam and compr weredefined:
IRsteamsteam = ––––– (21)
EIN
where IRsteam is the cumulative irreversibilityassociated to steam production and its mixingwith the syngas prior to entering the anode,and was calculated from a combined exergybalance applied to control volumes CV3 andCV4 in Figure 1:
Ewater + Eflue gs IN + Esyngas IN = CV3 CV3 CV4
Eanode input + Eflue gas OUT + IRsteamCV4 CV3 (22)
0
50
100
150
200
250
300
0 1000 2000 3000 4000 5000 6000 7000
pressurisedatmospheric
Uƒ = 0.650.75
0.85
0.650.75
0.85
P SOFC
in k
We
J in A/m2
Figure 3. SOFC power output (kWel) vs. current density (A/m2) foratmospheric and pressurised operation and three fuel utilisation ratios.
0
200
400
600
800
1000
1200
1400
1600
0.850.750.65
Uƒ
0
50
100
150
200
250
300
350
400
450
combustor T
additional air
TIT
Air a
dditi
on in
% o
f SOF
C re
quire
d
Post
-cel
l com
bust
or T
in K
(with
out a
dditi
onal
air)
Figure 4. Post-SOFC combustor temperature (K) and additional airexpressed as (%) of SOFC air for the pressurised operationvs. fuel utilisation ratio.
0
5
10
15
20
25
30
35
0 50 100 150 200 250 300
pressurisedatmospheric
0.65
0.75
Uƒ = 0.85
0.85
0.750.65
ηex
, SOF
C in
%
PSOFC in kWe
Figure 5. SOFC exergetic efficiency vs. SOFC power output (kWe)for atmospheric and pressurised operation and three fuelutilisation ratios.
EIN in kW
0
5
10
15
20
25
30
35
40
45
200 400 600 800 1000 1200 1400
0.75
0.65
0.65
pressurisedatmospheric
Uƒ = 0.85
Uƒ = 0.85
0.75
ηex
, el
in %
ηex, el (MGT)
Figure 6. Electric exergetic efficiencies of the three system configu-rations vs. biomass exergy throughput (kW).
CHP with Biomass Gasification and MGT
066-074_PT4_08.qxd 15.04.2008 12:00 Uhr Seite 71
72 VGB PowerTech 4/2008
CHP with Biomass Gasification and MGT
The second exergy loss ratio is associatedwith fuel cell compressor power consump-tion, because it is indirectly affected from thelevel of steam addition since the laterchanges the cooling demands of the stack:
Pcomprcompr = ––––– (23)
Ein
F i g u r e 8 a (pres-surised system)shows that the elec-trical efficiencymarginally deterio-rates with STCR be-cause despite steam
grows there is acounterbalancing re-duction of the compr,since the additionalsteam cools thestack replacing con-siderable amountsof air for this pur-pose. In all cases,the thermal through-put from the MGT
and therefore its contribution to power outputis constant (line PGT/Ein in Figure 8a) and theminor decrease in the electrical efficiency withSTCR is attributed to lower partial pressuresof reactants within the stack. Similarly, the lat-ter effect is evident in Figure 8b for the atmos-pheric operation. In both atmospheric andpressurised configurations the effect of the
level of additional steam requirement is re-flected on the CHP efficiencies (lines ex,CHP
and steam almost follow parallel trends) be-cause this affects the temperature at whichuseful heat is available from HX5.
Conclusions
The combination of biomass air gasificationwith SOFC and/or MGT for small-scale CHPwas assessed by modelling in AspenplusTM
process simulation software. Two system op-eration pressures were studied, atmosphericand ~ 4 bar. This small pressure shift doesnot have significant effect on the product gascomposition or on the exergetic efficiency ofthe gasification process. On the contrary, thepressurised SOFC operation is greatly im-proved, and with the additional power froman MGT expander, achieves the highest effi-ciencies ex,el ≥ 35 % at J values around 4000A/m2. The Uf was optimised at 0.85 for thepressurised and at 0.75 at atmospheric SOFCoperation for biomass throughputs of around200 kg/h. The atmospheric SOFC configura-
0
200
400
600
800
1000
1200
HX2
COM
PR.
AirQ
Flue gasoutlet
HX5
MGT
T in
K
Figure 7. Heat exchangers temperature profile for (a) pressurisedSOFC-MGT, (b) atmospheric SOFC and (c) pressurisedMGT configuration.
50
40
30
20
10
0
– 10
– 20
– 30
0.0 0.5 1.0 1.5 2.0 2.5
η &
ζ ra
tios
%
STCR
- ζ steam
- (ζ steam + ζ compr)
ηex, el
ηex, CHP
50
40
30
20
10
0
– 10
– 20
– 300.0 0.5 1.0 1.5 2.0 2.5
η &
ζ ra
tios
%
STCR
PGT / E in
- ζ steam
- (ζ steam + ζ compr)
ηex, CHP
ηex, CHP
Figure 8. Exergetic efficiencies and loss ratios vs. STCR for (a) pressurised, and (b) atmospheric operation with Uf = 0.85 (biomass throughput 200 kg/h).
0
200
400
600
800
1000
1200
HX2Post-cell
com-buster
Air
Q
Flue gasoutlet
HX5
Evap. Preheater
H2OT in
K
HX4 (HSRG)
0
200
400
600
800
1000
1200
MGT
HX2Post-cell
com-buster
HX4 (HSRG)
COM
PR.
Air Q
Flue gasoutlet
HX5
Evap. Preheater
H2OT in
K
a a
b b
c
066-074_PT4_08.qxd 15.04.2008 12:00 Uhr Seite 72
CHP with Biomass Gasification and MGT
tion results in considerably lower efficienciesthan the simpler pressurised gasificationMGT configuration which gives ex,el =23 %, and could only surpass this efficiencyif very low power densities were employed.Such a system would probably not be eco-nomic, i.e. to have the high SOFC-related in-vestment costs without significant revenuesfrom the power production. Through a de-tailed exergetic parametric analyses it wasshown that the increase of additional steamproduction to achieve a desired STCR doesnot greatly affect the electrical efficiencies ofthe SOFC configurations but is negatively re-flected on the combined thermal exergetic ef-ficiencies of the CHP systems because it dete-riorates the temperature at which off gases arefinally available for useful heat production.
References
[1] Higman, C., and Van Der Burg, M.: Gasifi-cation, Gulf Publishing, 2003.
[2] Maniatis, K., and Millich, E.: Energy frombiomass and waste: the contribution of utili-ty scale biomass gasification plants, Bio-mass and Bioenergy 1998; 15(3), 195-200.
[3] Baron, S., Brandon, N., Atkinson, A., Steele,B., and Rudkin, R.: The impact of wood-deri-ved gasification gases on Ni-CGO anodes inintermediate temperature solid oxide fuelcells, J. Power Sources 2004; 126(1-3), 58-66.
[4] Omosun, O., Bauen, A., Brandon, N. P., Adjiman, C. S., and Har,t D.: Modellingsystem efficiencies and costs of two bio-mass-fuelled SOFC systems, J. Power Sour-ces 2004; 131(1-2), 96-106.
[5] Vasileiadis, S., and Vasileiadoum Z. Z.:Biomass reforming process for integratedsolid oxide-fuel cell power generation, Che-mical Engineering Science 2004; 59(22-23),4853-4859.
[6] Singh, D., Hernández-Pacheco, E., Hutton,P. N., Patel N., and Mann, M. D.: Carbondeposition in an SOFC fuelled by tar-ladenbiomass gas: a thermodynamic analysisJournal of Power Sources 2005; 142(1-2),194-199.
[7] Prins, M.J., and Ptasinski, K.J.: Energy and exergy analyses of the oxidation and ga-sification of carbon, Energy 2005; 30(7),9821002.
[8] Bedringås, K. W., Ertesvåg, I. S., ByggstøylS., and Magnussen Bj. F.: Exergy analysisof solid-oxide fuel-cell (SOFC) systems,Energy 1997; 22(4), 403-412.
[9] Monanteras, N. C., and Frangopoulos, C.A.: Towards synthesis optimization of a fu-el-cell based plant, Energy Conversion andManagement 1999; 40(15-16), 1733-1742.
[10] Van den Oosterkamp, P. F., Goorse, A.A.,and Blomen, L.J.M.J.: Review of an energyand exergy analysis of a fuel cell system, J.Power Sources 1993; 41(3), 239-252.
[11] De Groot, A.: Advanced exergy analysis ofhigh temperature fuel cell systems, PhDThesis, Petten: Energy Research Centre ofthe Netherlands; 2004.
[12] Chan, S. H., Low, C. F., and Ding, O. L.:Energy and exergy analysis of simple solid-
oxide fuel-cell power systems, J. PowerSources 2002; 103(2), 188-200.
[13] Hotz, N., Senn, S. M., and Poulikakos, D.:Exergy analysis of a solid oxide fuel cellmicropowerplant, Journal of Power Sources,Volume 158, Issue 1, 14 July 2006, pp 333-347.
[14] Panopoulos, K.D., Fryda, L., Karl, J.,Poulou, S., and Kakaras, E.: High tempera-ture solid oxide fuel cell integrated with no-vel allothermal biomass gasification: Part II:Exergy analysis, Journal of Power Sources,Volume 159, Issue 1, 13 September 2006,pp. 586-594.
[15] Kapfenberger, J., Sohnemann, J., Schleitzer,D., and Loewen, A.: Acid gas removal bycustomised sorbents for integrated gasifica-tion fuel cell systems, 5th InternationalSymposium on Gas Cleaning at High Tem-peratures. U.S. Department of Energy Na-tional Energy Technology Laboratory, Mor-gantown, WV, September 17-20, 2002(available from: http://www.netl.doe.gov/publications/).
[16] Veyo, St. E.: Siemens Westinghouse PowerCorporation. Tubular SOFC Hybrids: Pre-sent and Prospect. In: Second DOE/UN In-ternational Conference and Workshop onHybrid Power Systems April 16-17, 2002.(available from: http://www.netl.doe.gov/).
[17] AspenPlus® Physical Property Methods andModels Reference Manual, Aspentech®, 1999.
[18] Kotas, T.J.: The Exergy Method of ThermalPlant Analysis, Krieger Publishing Com-pany, Malabar, Florida, 1995.
[19] Szargut, J., Morris, D. R., and Steward, F.R.: Exergy Analysis of Thermal, Chemical,and Metallurgical Processes, Taylor & Fran-cis Inc, 1988.
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066-074_PT4_08.qxd 15.04.2008 12:01 Uhr Seite 73
Heinrich-Mandel-Preis für Kraftwerkstechnik der VGB-FORSCHUNGSSTIFTUNGDie VGB-FORSCHUNGSSTIFTUNG wurde 1970 zur Förderung vonGemeinschaftsforschung auf dem Gebiet der Strom- und Wärmeerzeu-gung gegründet. Sie ist eine gemeinnützige Stiftung nach deutschem Pri-vatrecht. Der Vorsitzende der VGB-FORSCHUNGS-STIFTUNG ist Dr. Gerd Jäger. Das Stiftungskuratorium besteht aus insgesamt zehn Mit-gliedern, die Betreiber und Hersteller von Anlagen zur Erzeugung vonStrom- und Wärme sowie auf diesem Gebiet tätige Hochschulinstitute re-präsentieren.
Mit dem Heinrich-Mandel-Preis für Kraftwerkstechnikzeichnet die VGB-FORSCHUNGS-STIFTUNG seitüber 25 Jahren herausragende Leistungen junger Inge-nieurinnen und Ingenieure aus. Der Preis ist mit 10.000Euro dotiert und wird jährlich vergeben. Ausgezeich-net werden Arbeiten aus allen Gebieten der Kraftwerkstechnik. Dabeiwerden Kraftwerksbetrieb (einschließlich Planung und Bau) und zuzuord-nende Forschung als gleichwertig beurteilt. Das Höchstalter der Kandida-tinnen und Kandidaten liegt bei 35 Jahren.
Das Kuratorium der VGB-FORSCHUNGSSTIFTUNG vergab den Heinrich-Mandel-Preis für Kraftwerkstechnik 2007 zu gleichen Teilen an
– Dr. Lydia-Emilia Fryda für ihre Arbeiten zur Nutzung von Biomasse indezentralen Stro-merzeugungsanlagen < 1 MWel unter Einsatz einerWirbelschichtvergasung und von oxid-keramischen Brennstoffzellenund
– Dr. Jens Hampel für die Entwicklung eines Turbogenerators mit mechatronischer Netz-kopplung zur Wirkungsgraderhöhung kleinerDampfturbinen.
Die beiden Preisträger stellen die ausgezeichneten Arbeiten in dieserAusgabe der VGB PowerTech vor.
Heinrich-Mandel Prize for Power Plant Technology of the VGB Research FoundationThe VGB Research Foundation (VGB-FORSCHUNGSSTIFTUNG) wasfounded in 1970 to foster joint research in the field of power and heat generation. As a foundation of German private law it pursuessolely non-profit purposes. Chairman of the foundation is Dr. Gerd Jäger.The curatorship consists of ten members representing power plant opera-tors, the power plant manufacturing industry as well as university insti-tutes working in this field.
The VGB Research Foundation has rewarded outstand-ing performances of young engineers in the area ofpower plant engineering with the Heinrich-MandelPrize for more than 25 years. The prize is endowedwith 10,000 and is awarded annually. Eligible areworks from all fields of power plant engineering.
Equal significance is attributed to power plant operation (including plan-ning and construction) and related research. Limiting age of the candi-dates is at 35 years.In 2007, the Board of Trustees of the VGB-FORSCHUNGSSTIFTUNGequally awarded the Heinrich-Mandel Prize for Power Plant Technologyto– Dr. Lydia-Emilia Fryda for her works on the utilisation of biomass in
decentral electricity generation plants < 1 MWe with fluidised bedgasification and oxide ceramic fuel cells and to
– Dr. Jens Hampel for the development of a turbo generator with mecha-tronic link to the electrical grid for increasing the efficiency of smallersteam turbines.
Both prize winners present the awarded works here.
CHP with Biomass Gasification and MGT
[20] H. Morita, F., Yoshiba, N., Woudstra, K.,Hemmes, and Spliethoff, H.: Feasibility stu-dy of wood biomass gasification/molten car-bonate fuel cell power system -comparativecharacterization of fuel cell and gas turbinesystems, J. of Power Sources 2004; 138(1-2); 31-40.
[21] Kakaras, E., Vourliotis, P., Panopoulos, K.D., and Fryda, L.: Cotton residue gasificati-on tests in lab scale fluidised bed. Clean Air2003. Seventh International Conference onEnergy for a Clean Environment, 7 - 10 July2003, Calouste, Gulbenkian Foundation,Lisbon, Portugal.
[22] Peters, R., Riensche, E., and Cremer, P.:Pre-reforming of natural gas in solid oxidefuel-cell systems, J. Power Sources 2000;86(1-2), 432-441.
[23] Costamagna, P., Magistri, L., and Massar-do, A. F.: Design and part-load performanceof a hybrid system based on a solid oxidefuel cell reactor and a micro gas turbine, J.Power Sources 2001; 96(2), 352-368.
[24] Campanari ,S.: Thermodynamic model andparametric analysis of a tubular SOFC module, J. Power Sources 2001; 92(1-2), 26-34.
[25] Campanari, S., and Iora, P.: Definition and sensitivity analysis of a finite volumeSOFC model for a tubular cell geometry,Journal of Power Sources 2004; 132(1-2),113-126.
[26] Chan, S. H., Khor, K. A., and Xia, Z. T.: Acomplete polarization model of a solid oxidefuel cell and its sensitivity to the change ofcell component thickness, J. Power Sources2001, 93(1-2), 130-140.
[27] Chan, S. H., Low, C. F., and Ding, O. L.:Energy and exergy analysis of simple solid-oxide fuel-cell power systems, J. PowerSources 2002; 103 (2), 188-200.
[28] Selimovic, A.: Modelling of Solid OxideFuel Cells Applied to the Analysis of Integra-ted Systems with Gas Turbines, DoctoralThesis, Department of Heat and Power Engineering, Lund University, Sweden, 2002.
NomenclatureASOFC SOFC active surface (m-2)E Total exergy of a material stream (W)EQ
T Thermal exergy of a heat streamavailable at temperature T (W)
EW Work or power output (W)ER Equivalence ratioF Faraday constant
6.023�1023 �1.602�10-19 Cmol-1
h Enthalpy of a stream (J mol-1)ho Standard enthalpy at environmental
conditions (J mol-1)hfg Latent heat of water vaporisation
(2.442 kJ/kg)Ho
us Sulphur lower heating value (9.259kJ/kg)
I, J SOFC current and current density (A, A m-2)
IR Irreversibility of a process (W)LHV Fuel Low Heating Value (kJ kg-1 for
solids / MJ mn-1 for gases)
LHVfuel,dry Lower heating value, dry (17,567kJ/kg)
N Mole flow rate (mole s-1)ni Mole flow rate (mol s-1) of compo-
nent ip Pressure (bar) po Standard pressure = 1 (atm) PSOFC Direct current electric power
produced from the SOFC (W)PCOMP Air compressor power (W)PGT Gas turbine power output (W)Q Heat stream (W) R Universal gas constant
(8.314 kJ kmol-1 K-1)s Entropy of a stream (Jmole-1K)so Standard entropy at environmental
conditions (J mol-1)STCR Steam to carbon ratio
(refers to product gas) T Temperature (K)
To Standard temperature (K)Uf SOFC fuel utilisation factor VOC Open circuit (Nernst)
SOFC voltage (V)VOHM Ohmic SOFC voltage
over potential (V)VACT Activation SOFC voltage
over potential (V)VPO Polarisation SOFC voltage
over potential (V)�i Mole fraction of component i w Moisture mass fraction in fuel
(0.1 w/w)zs Sulphur mass fraction in fuel,
dry (0.09 w/w)
Subscripts / Superscripts cg cold gas CHP Combined heat and power overall
system el electrical ex exergetic gas Gasification IN Input OUT Output TIT Turbine Inlet TemperatureGreek symbols� Statistical correlation for solid fuel
exergy calculation�oi Standard chemical exergy of a com-
ponent i in a mixture (J mol-1)�ph Specific physical exergy of a material
stream (J mole-1)�ch Specific chemical exergy of a materi-
al stream (J mole-1)�o
s Chemical exergy of sulphur (18,676 kJ/kg)
�ch,fuel Fuel chemical exergy (kJ/kg) Exergy loss ratio associated with a
sub process IR over total Ein Efficiency �
066-074_PT4_08.qxd 15.04.2008 12:01 Uhr Seite 74
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