a life cycle evaluation of wood pellet gasification for district heating
TRANSCRIPT
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A life cycle evaluation of wood pellet gasification for district heating
in British Columbia
Ann Pa a, Xiaotao T. Bi a,, Shahab Sokhansanj a,b
a Clean Energy Research Centre for University of British Columbia, 2360 East Mall Vancouver, BC, Canada, V6T 1Z3b Environmental Sciences Division, Oak Ridge National Laboratory, Oak Ridge, TN 37831, USA
a r t i c l e i n f o
Article history:
Received 23 November 2010
Received in revised form 28 January 2011
Accepted 1 February 2011
Available online 5 February 2011
Keywords:
Life cycle analysis (LCA)
Wood pellets
British Columbia
District heating
Gasification
a b s t r a c t
The replacement of natural gas combustion for district heating by wood waste and wood pellets gasifi-cation systems with or without emission control has been investigated by a streamlined LCA. While stack
emissions from controlled gasification systems are lower than the applicable regulations, compared to
the current base case, 12%and 133% increases areexpected in the overall human health impacts for wood
pellets and wood waste, respectively. With controlled gasification, external costs and GHG emission can
be reduced by 35%and 82%on average, respectively. Between wood pellets andwoodwaste, wood pellets
appear to bethe better choice as it requires less primary energy and has a much lower impact on the local
air quality.
2011 Elsevier Ltd. All rights reserved.
1. Introduction
As climate change due to greenhouse gas (GHG) emissions is
gaining recognitions, various methods of climate change adapta-
tion and GHG emission mitigation have been proposed, discussed
and explored. Replacing a fraction of the current fossil fuel by
alternative energy sources such as bioenergy is one of the many
approaches recommended by policy makers. For instance, ethanol
blending requirement in transport fuel in the United States
reaches 1.14 EJ in 2010 and will increase to 3.18 EJ by 2022 while
the European Union target for renewable energy in the transport
sector in 2020 is set to 10%, or 1.29 EJ of biofuel (IEA and OECD,
2009; European Commission, 2007). Other than in the transport
sector, there are numerous studies that emphasize the potentials
of renewable energy, or more specifically bioenergy, in district or
residential heating and in combined heat and power systems
(CHP) (Difs et al., 2010; Bjrklund et al., 2001). The importanceof policy developments to promote the use of bioenergy in these
sectors is also discussed (Kopetz, 2007; Rickerson et al., 2009).
However, the use of biomass for district heating has been quite
controversial due to concerns with possible increase in health im-
pact (Ries et al., 2009). This concern is especially true when the
fossil fuel to be replaced is natural gas and when the community
is densely populated. There are currently a few major district
heating systems in Vancouver. These include one located in the
stadium and entertainment district in the core of downtown
(Davis, 2004) and three in Vancouvers largest hospital sites (Roger
Bayley Inc., 2009; Ministry of Energy of British Columbia, 2010).
The most recent establishment is the Southeast False Creek Neigh-
bourhood Energy Utility (NEU) which provides hot water and heat
for all new buildings in the area, including the Olympic Village that
was built to accommodate Olympic athletes participating in the
2010 Winter Olympic (City of Vancouver, 2010). The downtown
system operates on natural gas while the NEU operates on a
base-load system utilizing sewer heat recovery pump along with
a natural gas peaking/back-up boiler. There was a debate at the
beginning on the energy source to be chosen for the base-load sys-
tem and the two contenders were biomass and sewer heat (Roger
Bayley Inc., 2009). In the end sewer heat recovery heat pump sys-
tem was selected because of the public concerns on local air qual-
ity and traffic inconvenience that may arise from biomassutilization.
Another district heating system in Vancouver is at the Univer-
sity of British Columbia (UBC), where more than 99% of the heat
is generated fromnatural gas and the rest fromfuel oil during peak
season. With UBCs ambitious plan of reducing GHG to 33%, 67%
and 100% below the 2007 level by 2015, 2020 and 2050, respec-
tively, the University has devised a detailed plan of action. Replac-
ing natural gas with renewable energy is an important part of the
actions to be taken (University of British Columbia, 2010a). In fact,
$26 million CAD has been allocated for the establishment of a bio-
mass gasification cogeneration system on campus for research and
0960-8524/$ - see front matter 2011 Elsevier Ltd. All rights reserved.
doi:10.1016/j.biortech.2011.02.009
Corresponding author. Tel.: +1 604 822 4408; fax: +1 604 822 6003.
E-mail address: [email protected](X.T. Bi).
Bioresource Technology 102 (2011) 61676177
Contents lists available at ScienceDirect
Bioresource Technology
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demonstration purposes (University of British Columbia, 2010b).
Given UBCs strong motive to become green and the large amount
of GHG emissions from the boiler house, it is interesting to inves-
tigate the complete replacement of fossil fuels in its boiler house
with bio-based fuels. Wood pellets, made of sawmill residue, burn
cleaner than biomass residue and are produced in large quantity in
BC are thus consideredas a potential candidate. In 2008, 9 out of 30
pellet plants in operations in Canada are located in BC and about 35
Canadian pellet mills are in the planning stage with 13 of them tobe located in BC (Melin, 2008, unpublished data). Overall, about
90% of the pellets produced in Canada were exported and 78% of
these pellets were shipped to Europe (Melin, 2008, unpublished
data; Spelter and Toth, 2009). Finding domestic applications for
these pellets would result in less transportation-related GHG emis-
sions. The technology to be evaluated is gasification as it is cleaner
than direct combustion.
The replacement of UBCs current natural gas boiler house
with a wood pellet gasification system is evaluated by a stream-
lined life cycle analysis (LCA). LCA is a powerful tool for scenario
comparisons as the incremental variation between each scenario
would provide valuable insights for decision making. Up to date,
LCA has been used to examine the benefits and impacts of various
new projects such as the wastewater treatment and reuse system
in China (Zhang et al., 2010). As there have been many concerns
on the true impacts and degree of sustainability of biomass en-
ergy systems, LCA has been used extensively in recent years to
evaluate a wide range of bioenergy systems and, sometimes for
comparison purposes, fossil fuel energy systems. Some examples
include the study on lignocellulosic ethanol production (Spatari
et al., 2010; Gonzlez-Garca et al., 2010), biofuel production from
microalgae (Campbell et al., 2011; Collet et al., 2011) and biomass
district heating systems (Eriksson et al., 2007). Eriksson et al.
(2007) conducted a LCA study of district heating and CHP system
in Sweden using three different fuels: waste incineration, biomass
combustion and natural gas combustion. Another study at-
tempted to use LCA to investigate which of natural gas combus-
tion, wood pellet combustion, sewer heat recovery and
geothermal recovery would be the best choice for a district heat-ing system in Vancouver, BC, Canada (Ghafghazi et al., in press).
The study reveals that none of the energy sources has absolute
advantages over the others in all the impact categories considered
although by using renewable energy at least 200 kg of CO2-eqv
can be avoided per MWh of heat produced. Furthermore, the per-
formance of each type of energy source depends on many factors
such as electricity mix and types of energy utilized for producing
pellets.
For this study, an in-house life cycle inventory (LCI) database of
BC pellets (Pa et al., 2009) is utilized to evaluate a total of five sce-
narios for district heating at UBC. The base scenario is the current
installation and the others are wood waste gasification, wood pel-
let gasification and each of the two gasification operations with
emission controls. The wood waste gasification scenario utilizes
emission factors from the industry for wood waste gasificationwhile the pellet scenario uses estimated wood pellet gasification
emission factors based on literature values and wood waste gasifi-
cation emission factors from industry. For the scenarios with emis-
sion controls, an electrostatic precipitator (ESP) for dust control
and a selective catalytic reduction (SCR) unit for NOXcontrol are
included. The overall impacts on human health, ecosystem quality
and primary energy consumption in addition to GHG reduction
resulting from using wood waste and wood pellets are compared
to demonstrate the pros and cons of wood waste and wood pellet
utilization when replacing natural gas. The externality analysis
based on variations in emission profiles in different scenarios is
also performed to quantify the economical benefits for each
option.
2. Method and calculation
2.1. In-house BC pellet LCI Database
The functional unit for the in-house BC pellet LCI database is
one tonne (t) of wood pellets. Allocations are mass-based. The
streamlined life cycle consists of harvesting, transportation of har-
vested material to sawmill, sawmill processing, transportation of
sawmill by-products such as planer shavings and sawdust to pelletmill, pellet mill operations, pellet transportation in bulk via heavy
duty trucks (HDV, class 8, which has a gross vehicle weight rating
of above 15 t) and train to port in North Vancouver. For this study,
the transportation of pellets from port in North Vancouver to UBC
campus and the pellet usage in the UBC gasification/combustion
boiler are also included. The 20.2 km transportation from port in
North Vancouver to UBC is by HDV. Emissions from infrastructures
and land use changes are not included in the database in view that
pellets in BC are made from sawmill residue and forest residue.
The pollutants investigated are CO2, CH4, N2O, CO, non-methane
volatile organic compound (NMVOC), NOX, SOX and particulate
matters (PM). Other pollutants in trace amounts, although avail-
able in some databases, are not included in this study for consis-
tency reasons. CO2
is categorized as either fossil or biogenic.
However, CH4and CO are separated into biogenic or generic where
generic may contain a small amount of biogenic emissions as not
all emission data used segregated fossil and biogenic emissions
of CH4 and CO. Note that all indirect emissions are also included
in the analysis. For instances, emissions produced during produc-
tion and transportation of fuels are all accounted for in the
database.
Energy consumption data during harvesting and sawmill oper-
ations are obtained from Sambos (2002) and Nyboers (2008)
work, respectively. Information gathered from a few member com-
panies of Wood Pellet Association of Canada provided energy con-
sumption data for pellet mill and port operations. The different
types of energy considered are electricity, natural gas, heavy fuel
oil (HFO), middle distillates (diesel), propane, steam, wood waste
and gasoline. The primary energy consumptions are included inthis database and the electricity mix used is specific to BC. Details
regarding various transportation segments are also obtained from
the surveys.
The pellet LCI database was presented in the 8th World Con-
gress of Chemical Engineering in Montral (Pa et al., 2009) and will
be released in a follow-up publication with more details. The
methodology used to establish this database is used to construct
all the scenarios in this study.
2.2. UBC district heating system
For this study, a total of five scenarios will be investigated. The
base case is the current operation and the four woody biomass gas-
ification systems are wood waste, wood pellets and each of these
two systems equipped with ESPs with 99% PM removal efficiencyand SCR with 80% NOXremoval efficiency.
The values presented in this work are either per MJ of fuel input
or per year of operation. The annual operation is based on the
amount of heat that is currently generated in the base scenario
on a yearly basis, which is 974 TJ. This is chosen as the functional
unit because the amount of heat to be produced in a year is iden-
tical for all scenarios thus allowing for scenario comparison, which
is also equivalent to the functional unit of per unit of energy
produced.
2.2.1. Base scenario
The current facility configuration consists of boilers where the
fuels (natural gas and fuel oil) are fed into. The fuels are combusted
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to heat up the entering water stream to produce steam at 165 psig
(1138 kPa) that is then distributed around the campus. The flue gas
from the boilers is directed to an economizer to preheat the water
entering the boiler before the flue gas exits the facility. For the base
case, the stages in the LCA of both natural gas and oil include pro-
duction of fuels, their transportation or transmission to UBC, and
emissions during the end usage at the current facility. The emis-
sion factors for natural gas and fuel oil production and transmis-
sion are obtained from GHGenius v3.17 (Delucchi and Levelton,2010) and are referred to as upstream emission factors. In GHGe-
nius, CH4 and CO emissions from both fossil and biomass origins
are not segregated and are both reported simply as CH4 and CO.
By default, GHGenius does not display biogenic emissions of CO 2but this can be altered so biogenic CO2emission values can be ex-
tracted. The combustion emission factors for the current installa-
tion are from the Combustion Test Report provided by UBC boiler
house (Northwest Instrument Systems Inc., 2009), EMEP CORINAIR
Emission Inventory Guidebook (European Environment Agency,
2007) and US EPA AP-42 documents (US Environmental Protection
Agency, 1995). For the CombustionTest Report, the boiler was fired
with different fuels and at different capacities. The emissions were
higher if the equipment was operated at a lower capacity. For the
purpose of this study, the emission factors at 50% capacity are se-
lected. The emissions were reported as concentrations (in ppmv) of
the flue gas so material balance is carried out to determine the flue
gas flow rate. For natural gas firing, SOXemission is assumed to be
0 as sulfur content in the BC natural gas is negligible. Table 1lists
the total emission factors of the UBC boiler running on natural gas
and fuel oil with the sources of emission factors specified. The cur-
rent amount of steam production is further explained in detail in
the following section for easy comparison with the woody biomass
scenarios.
2.2.2. Woody biomass gasification scenarios
The system boundary and stages for the wood pellet scenario
have already been described earlier in the In-house BC pellet LCI
Database section. The life cycle stages for the wood waste gasifi-
cation scenarios include the production of two types of wood res-idues and their transportation, and the final usage at UBC. The two
types of wood residues are forest harvesting residues and sawmill
residues.
The forest residue production started from harvesting operation
with data taken fromSambo (2002). The forest residue is chopped
in the forest using mobile chopper andthe emissions related to this
process are from US-EI (Swiss Centre for Life Cycle Inventories
et al., 2008). The chopped residue is then transported to railhead
via HDV over a distance of 150 km. From the railhead to the North
Vancouver shipping port, the train would travel 350 km. From the
shipping port, the forest residue would be delivered to UBC district
heating facility via HDV over a distance of 20.2 km.
For the sawmill and planer mill residue, the harvesting of wood
for the forest and sawmill operations are all included and emission
data are based on literature used for the pellet LCI but convertedaccordingly so that the functional units are per tonne of wood res-
idue with 51% moisture content, dry basis. The sawmill residue
would be transported to the railhead via HDV over a distance of
25 km. The residue then travel by train for 350 km before arriving
the North Vancouver port. The residue is then delivered to UBC via
HDV over a distance of 20.2 km. The distances used in the calcula-
tions are estimated based on harvest field and sawmill locations in
BC, Canada (Natural Resources of Canada, 2003a,b) and opinions
from the local industry (Melin, 2010, personal communication).
The final wood waste to be gasified is assumed to have a mois-
ture content of 60%, dry basis, as that is maximum moisture con-
tent allowed for smooth operation of the gasifier. Due to this
limitation, some natural drying/aging is assumed to happen at
UBC and the moisture content difference between the fuel deliv-
ered and the fuel fed into the system is taken into account.
The proposed biomass utilization system for woody biomass
gasification is a retrofitted air gasification system because gasifica-
tion generally produces lower PM, CO, VOC (volatile organics) and
NOXemissions compared to direct combustion (European Environ-
ment Agency, 2007; Sparica, 2009, personal communication). The
syngas produced is combusted in the existing natural gas combus-
tor to heat up water in the boiler to generate steam. The flue gas
can be treated with an ESP to remove PM and/or a SCR unit to re-
move NOXif required.
The thermal efficiency of this system depends on the moisture
content of the biomass fuel. Typical thermal efficiency for biomass
fuel with approximately 60% moisture content (dry basis) is 62%
(Sparica, 2009, personal communication) and this is the thermal
efficiency assumed for the wood waste scenarios. For biomass with10% moisture content, the thermal efficiency is 78% (Sparica, 2009,
personal communication). This number is used for wood pellet sce-
narios despite the moisture content of BC wood pellets is actually
around 6%. Combining thermal efficiency and the amount of steam
produced in 2008, it is deduced that 126,015 t of wood waste, with
a gross calorific energy content at 12.50 MJ/kg (Forest Product
Table 1
Estimated total emission factors for UBC boiler house and their sources.
Fuel oil-firing boiler Natural gas-firing boiler
Total emission
factor (g/GJ of
fuel used)
Source of emission factor Total emission
factor (g/GJ of
fuel used)
Source of emission factor
Upstream Combustion Upstream Combustion
CO2, fossi l 88,593 Delucchi and
Levelton (2010)
European Environment
Agency (2007)
53,393 Delucchi and
Levelton (2010)
Northwest Instrument Systems
Inc. (2009)
CO2, biogenic 475 0 79.9 0
CH4 120 European Environment
Agency (2007)
72.3 European Environment
Agency (2007)N2O 7.97 1.67
CO 26.1 US Environmental Protection
Agency (1995)
9.14 Northwest Instrument Systems
Inc. (2009)
NMVOCa 22.8 European Environment
Agency (2007)
5.05 European Environment
Agency (2007)
NOX 89.8 Northwest Instrument Systems
Inc. (2009)
36.1 Northwest Instrument Systems
Inc. (2009)
SOX 245 Mass balance based on input S
content fromPodolski et al. (2008)
6.09 Mass balance based on input S
content
PM 5.73 European Environment Agency (2007) 0.49 European Environment
Agency (2007)
a Non-methane volatile organic compounds.
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Laboratory, 2004), is required annually to produce the same
amount of steam as the base case. For the wood pellet scenarios,
64,257 t of wood pellets, with a gross calorific energy content at
19.4 GJ/t (Accredited Laboratory, 2007), is required. Just for com-
parison, in 2008 the boiler house consumed 1034 TJ of natural
gas and 7.84 TJ of fuel oil to generate 350 kt of steam at 165 psig
(1138 kPa), translating to 974 TJ of heat produced (UBC Utilities,
2009). These numbers correspond to a 93% overall thermal
efficiency.
2.2.1.2. Woody biomass gasification emission factors. For the wood
waste scenarios, the gasification emission factors utilized were
based on wood waste gasification in a commercial fixed bed gas-
ifier. The biogenic CO2 emission is calculated based on the carbon
content of wood. It was assumed that the carbon content in dry
wood is 50% and the moisture content of wood waste, a mixture
of forest residue and sawmill and planner mill residue, is 60%,
dry basis, which is the maximum moisture allowed for the gasifier.
At 60% moisture content, the mixed waste would give off 0.092 kg
of biogenic CO2 emission per MJ of pellets gasified. The CH4, N2O
and SOXemission factors are not available so they are estimated
by the emissions of wood waste combustion in boiler from US
AP42 document (US Environmental Protection Agency, 1995). The
annual emissions are obtained by multiplying the emission factors
by the annual fuel consumption.
It is speculated that wood pellet gasification emission factors
may vary quite substantially given that the combustion emission
for wood waste and wood pellets do vary considerably as shown
in the literature or published database (Swiss Centre for Life Cycle
Inventories, 2008; Johansson et al., 2004; Wierzbicka et al., 2005;
Lillieblad et al., 2004). In attempt to better represent wood pellet
gasification emissions in the wood pellet scenarios, which are not
available in the literature, the emission factors are estimated using
two types of ratios. The first ratio is the ratio between wood and
pellet combustion emission factors from literature and database.
This first ratio together with the wood gasification emission factors
from the industry can yield a set of estimated emission factors for
the wood pellet gasification system. The second ratio is the ratiobetween published wood combustion emissions and the wood gas-
ification emission from the industry. This ratio can then be applied
to pellet combustion emission factors from literature and database,
resulting in another set of estimated emission factors for pellet
gasification, provided that the values of pellet and wood combus-
tion emissions are different from those used to calculate the first
ratio, as that would yield two identical sets of wood pellet gasifica-
tion emission factors.
In order to carry out this approximation process based on ratios,
it is crucial to compare data with similar set-up in terms of emis-
sion controls, system type and type of biomass used. Different
emission data are matched based on considerations mentioned
and whenever possible, data from the same article or database
are compared. For the calculation of the first type of ratio, no unit
conversion is required as the units used are usually consistentwithin a single source. However, when calculating the second type
of ratios, unit conversions need to be performed as industrial emis-
sion data for wood gasification are provided in mass of pollutant
per energy unit of wood utilized while most literature report their
data in mass of pollutant per volume of flue gas with the O2% or
CO2% of flue gases provided along with the specification on dry
or wet gas basis. Conversions of units are performed as described
in The Handbook of Biomass Combustion and Co-firing (van Loo
and Koppejan, 2007). Since gasification emission factors from the
industry do not include CH4and N2O, their ratios are not calculated
and pellet combustion emission factors from the US-EI database
are used in the estimated pellet gasification emission data.Table 2
lists all the emission factors used in the calculation of the ratios. Table
2
Listofpelletandwoodcombustionemissionfac
torsfrom
literatureinkgofpollutantemittedperMJoffuelutilized.
Source
Wierzbickaetal.
(2005
)
Pagelsetal.
(2003)
Johanssonetal.
(2004)
USEnviron
mental
ProtectionAgency
(1995)
SwissCentrefor
LifeCycleInventories
etal.
(2008)
Lilliebladetal.
(2004)
Fuel
Forestresidue
Pellet
Forestresidue
Mixedwood
Pellet
Wetwood
Mixedwood
chip
fromforest
Pellet
Shaving
chips,
andsawdust
Pellet
Load
Medium
High
Medium
80%
60%
45%
Low
Low
Emissioncontrol
Multicyclone
Multicyclone
None
Multi
cyclone
M
ulticyclone
Typeofequipment
1.5
MW,
movinggrate
1MW,
movinggrate
Emission
median
forpelletboiler
Emission
median
forpelletboiler
Furnace,
50kW
1.5
MW,
m
ovinggrate
BiogenicCO2
9.1
7E02
9.1
7E02
1.0
3E01
9.6
5E028.9
3E02
7.8
5E02
BiogenicCH4
4.3
5E05
1.7
7E06
9.0
3E06
9.0
3E06
7.0
0E07
3.0
0E07
N2O
5.5
9E06
5.5
9E06
3.0
0E06
2.5
0E06
BiogenicCO
4.1
0E03
3.2
0E04
2.5
8E04
2.5
8E04
1.1
8E04
6.5
0E054.0
0E04
3.4
4E05
NMVOC
2.8
5E05
2.5
0E06
7.3
1E06
7.3
1E06
9.0
0E07
1.5
0E06
NO
X
7.2
0E05
6.7
0E05
9.4
6E05
9.4
6E05
1.1
0E04
7.4
0E053.3
1E05
4.6
7E05
SOX
1.0
7E05
1.0
7E05
2.5
0E06
2.5
0E06
PM2.5
3.4
0E05
2.0
0E05
PM
4.4
6E05
6.8
8E05
1.8
7E05
8.1
0E05
5.5
9E05
4.5
4E05
8.8
0E05
1.9
0E05
1.4
2E04
9.4
6E05
4.3
0E05
2.3
7E052.1
6E05
2.1
6E05
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Table 3 summarizes the two set of emission factors obtained
from the two types of ratios and their average values. The average
estimated pellet gasification emission factors are used for the cal-
culation in uncontrolled pellet scenario in this study. Note that SOXis manually set to zero since SOXemission depends mostly on the
sulfur content of the fuel and wood pellet contains negligible sulfur
at less than 0.01%, dry basis (Johansson et al., 2004).
2.2.1.3. Emission controlled woody biomass gasification scenarios.
Table 3also includes the current air emission limits, in kg per MJof fuel consumed, for biomass boilers and heaters in Metro Van-
couver (Metro Vancouver, 2008) and the wood waste gasification
emission factors used in this study. It is apparent that emission
control units need to be in place in order to stay below the local
air emission limit. The numbers show that NOX and PM need to
be reduced by 37% and 66%, respectively for wood pellet and 44%
and 87% for wood waste gasification. Both can be easily achieved
by technologies such as SCR for NOXreduction and ESP for PM re-
moval as the typical removal efficiencies for these units are
approximately 80% and 99%, respectively (Forzatti, 2001; De
Nevers, 2000). These efficiencies are applied for the controlled
woody biomass gasification emission scenarios.
2.3. Life cycle impact assessments of the scenarios
Biogenic CO, CO2 and CH4 have the same impacts as non-bio-
genic emissions in terms of human and ecosystem quality as the
chemical structure does not depend on the origin of emissions.
However, in terms of climate change impact, biogenic CO, CO2and CH4are considered to have less impact than their fossil-origin
counterparts as biogenic carbon emissions are considered to be
carbonneutral and do not result in net-increase in the carbon con-
tent of the atmosphere. By definition PM is for all particulate mat-
ters while PM2.5 refers to those less than 2.5lm and PM10 are
those less than 10 lm. PM2.5 are the ones with significant health
impacts (Humbert et al., 2005). The impact factors for PM are esti-
mated based on an average PM2.5to PMratio in ambient air of 0.33
(Humbert et al., 2005; Dockery and Pope, 1994). Throughout this
study, care was taken to avoid double accounting. When only PMemission factors are available, such as from GHGenius database
(Delucchi and Levelton, 2010), they are used and the impacts are
calculated using PM impact factors. When both PM and PM2.5emission factors are available, only the PM2.5 emission factors
and thus impacts are utilized. In the result section, sometimes both
PMand PM2.5are listed, but it is important to acknowledge that for
each process, only one of the PM or PM2.5 emission factors, and
thus their respective impact factors, is used, not both.
The emission factors and energy consumption data are im-
ported into a commercial LCA software, SimaPro, to allow for the
use of various life cycle impact assessment (LCIA) methods. IM-
PACT 2002+ (Jolliet et al., 2003) is selected for impact assessment
in this case study. IMPACT 2002+ includes both midpoint and
end point impacts by linking all life cycle inventory data via 15
midpoint categories to four damage, or end point, categories, as
illustrated inFig. 1. The dashed lines indicate that the conversion
into damage categories has not yet been properly established.
The units used for each impact category, such as DALY and
PDFm2 yr, are defined inFig. 1.
The most current version of IMPACT 2002+ at time of analysis
(v2.06) is adapted for analysis with two extra categories added to
keep track of the primary energy consumption and external costs
throughout the entire life cycle. These two new end point catego-ries are also presented inFig. 1. The impacts of biogenic CH4 and
CO are added under the categories of respiratory organic and inor-
ganic, respectively, using the impact values of their fossil fuel ori-
gin counterparts. Six endpoint categories, human health,
ecosystem quality, climate change, primary energy consumption,
external cost and resources can be obtained. Only the first five will
be evaluated in this study. It is important to keep in mind that IM-
PACT 2002+ was developed in Europe so the values of parameters
used for the compilation of human toxicity are at a continental le-
vel for Western Europe. Due to this reason, the final values to be
presented here only serve as indicators for scenario comparisons
as the absolute values may not be so meaningful due to geograph-
ical and geological differences in Western Canada and Western
Europe.
External cost, also known as externality, is the unaccounted anduncompensated impact on a group arising from the social or eco-
nomic activities of other groups (European Commission, 2003).
Table 3
Estimated wood pellet gasification emission factors and air emission limits for biomass boilers in Vancouver, Canada.
Pol lutant Wood waste
gasification emission
factors (kg/MJ)
Estimated pellet gasification
emission factors based on
ratio 1 (kg/MJ)
Estimated pellet gasification
emission factors based on
ratio 2 (kg/MJ)
Average estimated pellet
gasification emission
factors (kg/MJ)
Vancouver air emission
limit for biomass boilers
(kg/MJ)
Biogenic CO2 9.17E02 8.50E02 8.22E02 8.36E02
Biogenic CH4 9.03E06 3.00E07 3.00E07 3.00E07
N2O 5.59E06 2.50E06 2.50E06 2.50E06
Biogenic CO 1.46E05 1.26E06 1.14E06 1.20E06 1.59E04
NMVOC 4.30E06 3.77E07 3.02E07 3.39E07
NOX 7.31E05 6.80E05 6.33E05 6.56E05 4.10E05
PM 4.00E05 1.92E05 1.14E05 1.53E05 5.13E06
Fig. 1. Overall scheme of the IMPACT 2002+ framework, linking LCI results via the
midpoint categories to damage categories with modifications implemented for this
study (based onJolliet et al., 2003).
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Therefore, externality reflects the impact on environment and hu-
man health. Table 4 lists three sets of reported external costs for air
pollutants investigated in this study. The costs for biogenic CO2,
CH4 and CO are estimated using the impact factors for different
pollutants in IMPACT 2002+. The global warming factors listed in
IMPACT 2002+ are mostly based on IPCC 2001s 500-year time
horizon values. Since CO2 only has an effect on climate change
and biogenic CO2 has no impact, biogenic CO2 has been assigned
a zero external cost. It is noted that the average external cost for
CH4 in the literature is close to $0.23, which is equal to the cost
of CO2 multiplied by the impact factor of CH4, a value of seven.
The same observation is made for N2O where the calculated valuebased on its impact factor of 156 is $5.15. Based on these observa-
tions, the external cost of biogenic CH4is estimated by multiplying
its impact factor of 4.25 by the cost of CO2 to yield $0.14. This is
plausible as CH4 only has effects on global warming according to
IMPACT 2002+. For biogenic CO, it also has impact on human
health, which is the total cost of CO minus the cost of climate
change. With the cost of climate change for CO being estimated
as the cost of CO2 multiplied by the climate change impact factor
for CO in IMPACT 2002+, which is 1.57, the health cost for CO is
found to be $0.67, which applies to CO from all sources. Since
the climate change impact factor of biogenic CO is 0, the total cost
of biogenic CO is equal to the health cost of CO. The emission
reduction achieved from replacing natural gas and fuel oil with
wood pellets can then be combined with external cost for each pol-
lutant inTable 4to derive the reduction in external costs.Since health impact depends heavily on the emission location
and its proximity to population, the health impact associated with
end usage alone for all five scenarios are compared as the point of
usage is at UBC campus, where the risk of exposure to pollutant is
much higher compared to pellet mills in suburban areas. The end
stage health impacts for all scenarios are normalized by the value
of the base scenario as it is the relative, not the absolute, values of
the health impact that are relevant for this comparison.
3. Results and discussion
Using values presented inTable 1, the current annual emissions
from UBC boiler house are calculated and presented in Table 5,
together with the emissions from all the biomass gasification sce-
narios. The emission factor for PM instead of PM2.5is provided for
all processes in the life cycle except for steam generation, where
the PM2.5 emission factor is provided instead of PM. Due to this
reason, there are both PM and PM2.5emissions reported inTable 5
but there is no overlapping between them as the emission factor
for PM during steam generation was not used in the calculation.
From Table 5 it is apparent that the estimated biogenic CO,
NMVOC, NOXand PM emissions for pellet gasification are lower
than wood waste gasification, as observed in pellet and wood
waste combustion. It appears that the most obvious advantage of
switching to woody biomass gasification is the drastic reductionof CO2emissions of fossil fuel origin. However, this is coupled with
a substantial increase in biogenic CO2emission, particularly due to
lower thermal efficiency for the biomass gasification system and
the high carbon intensity of biomass energy. Another emission
reduction lies in generic CH4. Even though there is a slight increase
of biogenic CH4 emission, there is a net CH4 reduction of 64% and
77% when accounting CH4from all origins for wood waste and pel-
let gasification, respectively. The high CH4emission from the cur-
rent scenario arises from the upstream processing of natural gas
as well as the leakage and loss during pipeline transmission. This
observation is more noticeable inFig. 2where the stage-wise dis-
tribution of each pollutant for the current scenario is illustrated. It
is evident from the same figure that natural gas burns very cleanly
with most of the emissions from upstream, with the exception of
fossil CO2, N2O and NMVOC. Despite that natural gas combustionand upstream operations seem to be contributing the most to the
emissions and environmental impacts, it is important to note that
more than 99% of the energy input was from natural gas thus Fig. 2
does not suggest that fuel oil burning is cleaner than natural gas.
However, it is noted that there is a significant SOXemission from
oil combustion despite that only less than 1% of the energy input
was from fuel oil.
Other than generic CH4emission and CO2emission of fossil ori-
gins, all other emissions would increase when the boiler is
switchedfrom natural gas to woody biomass gasification. The most
significant increase, other than in biogenic CO2, is in PM emissions,
reaching approximately 130- and 77-folds for wood waste and
wood pellets, respectively. Even with an ESP unit, the increase
Table 4
Summary of external costs from literature and the external costs used in this study.
Bi and Wang (2006) Average values from various
states in the US a Golay (2005)
Dones et al. (2005) Values used in this analysis Calculation and remarks
CAD $/kg CAD $/kg CAD $/kg CAD $/kg
CO2, fossil 0.04 0.03 0.03 0.03 Average of all values
CO2, biogenic 0 Estimated using impact factors in
IMPACT 2002+ method
CH4 1.05b 0.25 NA 0.25 State average value is used as it is
not just estimation based on GWP
CH4, biogenic 0.14 Estimated using impact factors in
IMPACT 2002 + method
N2O 12.52b 4.73 NA 4.73 State average value is used as it is
not just estimation based on GWP
CO 0.41 1.02 NA 0.72 Average of all values
CO, biogenic 0.67 Estimated using impact factors in
IMPACT 2002 + method
NMVOC NA NA 1.78 1.78
VOC NA 3.76 NA 3.76
NOX 5.23 6.41 4.59 5.41 Average of all values
SOX 5.46 2.30 4.64 4.14 Average of all values
PM 14.70 3.14 18.52c 12.12 Average of all values
PM2.5 NA NA 30.87 30.87
a Based on values from New York State Public Service Commission, Department of Public Utilities of Massachusetts, Public Service Commission of Nevada and
California Public Utilities Commission and presented in Golays lecture slides (Golay, 2005).b Estimated by source based on CO2cost multiplied by specific pollutants 100 years time horizon GWP (global warming potential) value from the 2007 IPCC report.c Estimated by source based on typical PM2.5/PM ratio.
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would still be approximately 17- and 43-folds for wood waste and
pellet, respectively. ESP appears to be less effective for the pellet
scenario because a large portion of PM emission is released from
the upstream fuel preparation process, which is not controlled by
the ESP installed for the gasification plant. For wood pellet sce-
nario, approximately 31% of the total PM emission is from pellet
mill where wood residue is burned for biomass drying. Thus,
removing PM from gasification process alone would achieve a less
significant PM reduction over the entire life cycle. However, it isimportant to point out that the zero emission of PM2.5under cur-
rent natural gas operation results from the fact that all emission
factors related to base scenario are only for PM but not for PM2.5specifically. With emission controls in place, the increase in other
pollutant emissions ranges from 215% (for NMOVC) to 448% (for
N2O) for wood waste and 42% (for SOX) to 393% (for all CO), for
wood pellets.
InFig. 3, the stage-wise contributions to the total emissions are
illustrated for wood waste gasification (Fig. 3a), wood pellet gasifi-
cation (Fig. 3b), wood waste gasification with emission controls
(Fig. 3c) and wood pellet gasification with emission controls
(Fig. 3d), respectively.Fig. 3 reveals that the top contributor to bio-
genic CO2and N2O emissions is the gasification stage for all woody
biomass gasification scenarios. For the uncontrolled wood waste
scenario, more than 80% of the generic CO and approximately
50% of the NMVOC emissions are emitted during the harvesting
stage. The gasification stage is the main contributor to the remain-
ing pollutants except for fossil-origin CO2and generic CH4as more
than 40% of each of these pollutants are emitted during harvesting.
For wood waste gasification with emission control units, the har-
vesting stage also becomes the main contributing stage for NOXand PM emissions throughout the life cycle and remains to be
the main contributor for fossil-origin CO2 and generic CH4.
For both uncontrolled and controlled wood pellet scenarios, the
harvesting stage is the main contributor to fossil-origin CO2, gener-
ic CO, NMVOC, and SOXwhile pellet mill is where the majority of
biogenic CH4and CO is emitted due to the burning of wood residue
within the mill. In the uncontrolled pellet scenario, 42% of the NOX
emission in the life cycle is emitted in the harvesting stage and 40%from gasification. Moreover, gasification is responsible for 44% of
the life cycle PM emission. However, with emission control, gasifi-
cation stages contribution to PM and NOXare reduced to 0.8% and
12%, respectively, with pellet mill becoming the new hot-spot for
PMemission. Note that the PM categories in both Figs. 2 and 3 refer
to All PM inTable 5.
The external costs from each scenario are also presented inTa-
ble 5. By switching to wood waste gasification, there is actually an
increase of $450,000 CAD in external costs while wood pellet gas-
ification would result in an $87,000 CAD saving. It was stated ear-
lier that in order to satisfy the air emission limits in Vancouver for
biomass boiler theNOX and PMemissions need to be reduced. With
the installation of SCR and ESP units, these two pollutants can be
reduced by 80% and 99% thus achieving emissions much lower
than what is required. With the emission control units, the exter-nal costs can be reduced by 38% and 31% from the base case for
wood waste and wood pellets, respectively. Note that no spatial
variation of the external cost has been considered in the current
analysis in which the emissions released in densely populated ur-
ban area and less populated remote area are given the same exter-
nal cost for each gas pollutant.
Since emissions are increased for all major pollutants when the
boiler house is switched from natural gas to wood pellet gasifica-
tion, it is hard to comprehend the relative overall impacts from
each scenario based on emission inventories only.Fig. 4compares
each of the five scenarios impacts on human health, ecosystem
quality and climate change, as well as a breakdown of these
Table
5
Annualairemissionsfrom
currentandwoodpe
lletscenarios.
Uncontrolledwoodybiomassgasification
Controlledwoodybiomassgasificationa
Emissionsforbase
Scenario(t/yr)
Emissionsfor
woodwaste(t/yr)
Reductioninexternal
cost($1000CAD)
Emission
sfor
woodpe
llet(t/yr)
Reductioninexternal
cost($1000CAD)
Emissionsfor
woodwaste(t/yr)
Reductioninexternal
cost($1000CAD)
Emissionsfor
woodpellets(t/
yr)
Reductioninexternal
cost($1000CAD)
AllCO2
55,9
97
154
,205
1,5
06
121,5
52
1,5
52
154,2
05
1,5
06
121,5
52
1,5
52
CO2,
fossil
55,9
11
8
,629
1,5
06
8,8
77
1,5
52
8,6
29
1,5
06
8,8
77
1,5
52
CO2,
biogenic
86.3
0
145
,575
0.0
0
112,6
76
0.0
0
145,5
75
0.0
0
112,6
76
0.0
0
AllCH4
75.7
0
27.1
8
13.8
3
17.5
2
14.7
9
27.1
8
13.8
3
17.5
2
14.7
9
CH4
75.7
0
12.8
5
15.8
4
16.3
6
14.9
6
12.8
5
15.8
4
16.3
6
14.9
6
CH4
b,b
iogenic
0.0
0
14.3
3
2.0
1
1.1
7
0.1
6
14.3
3
2.0
1
1.1
7
0.1
6
N2O
1.7
9
9.8
1
37.8
9
4.6
3
13.4
0
9.8
1
37.8
9
4.6
3
13.4
0
AllCO
9.6
5
47.7
3
25.9
7
47.6
0
25.9
8
47.7
3
25.9
7
47.6
0
25.9
8
COb
9.6
5
21.6
2
8.5
9
23.4
3
9.8
9
21.6
2
8.5
9
23.4
3
9.8
9
CO,b
iogenic
0.0
0
26.1
0
17.3
8
24.1
7
16.1
0
26.1
0
17.3
8
24.1
7
16.1
0
NMVOC
5.4
0
17.0
1
20.6
2
11.7
9
11.3
4
17.0
1
20.6
2
11.7
9
11.3
4
NOX
38.0
4
219
980
203
893
127.0
0
481
137.5
6
539
SOX
8.2
2
127.0
0
77.8
1
11.6
4
14.1
1
27.0
4
77.8
1
11.6
4
14.1
1
AllPM
0.5
6
72.5
5
882
43.5
5
522
10.1
8
126
24.6
3
292
PM
0.5
6
72.0
6
867
43.5
2
521
9.6
9
111
24.5
9
291
PM2.5
c
0.0
0
0.4
9
15.2
0
0.0
3
1.0
1
0.4
9
15.2
0
0.0
3
1.0
1
Totalchangesin
externalcost
450
87
804
671
aselectivecatalyticreduction(SCR)hasaremovalefficiencyof80%whileelectrostaticprecipit
atorhasaPMremovalefficiencyof99%.
bmayincludesomebiogenicemissionsasw
ell.
cfromsteamgenerationonlyasnoPMem
issionfactorwasavailableforthisprocess.
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impacts into different stages to signal out hot-spots throughout
their life cycles.
By switching to woody biomass, both impacts on human health
and ecosystem quality increase significantly. For human health, the
current impact is 4 DALY and it would increase by 6.2- and 8.6-
folds for wood pellets and wood waste, respectively. Even with
emission control units, the increase would still be 3.3-folds on
average for both woody biomass fuels. Since the parameters used
in the impact assessment method are based on Western Europe,care should be exercised in the interpretation of human health
impact.
The current impact on ecosystem quality is 2.26E5 PDF m2 yr
and it would increase by around 4.7 and 4.2 times when switched
from natural gas to wood waste and wood pellet gasification sys-
tems, respectively. With SCR and ESP, the increase can be lowered
to an average of 2.4-folds for both fuel types.
FromFig. 4it becomes apparent that the harvesting of woody
material and the gasification stage contribute greatly to humanFig. 2. Stage-wise emission distribution for current natural gas boiler scenario.
Fig. 3. Stage-wise emission distribution for (a) wood waste gasification, (b) wood pellet gasification, (c) wood waste gasification with SCR and ESP units with 80% NOXand
99% PM removal efficiency, respectively, and (d) wood pellet gasification with identical emission control units.
6174 A. Pa et al./ Bioresource Technology 102 (2011) 61676177
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health impact. It is evident that by adding emission control units,
the pellet scenarios human health impact for the entire life cycle
can be further reduced by 35% while the health impact associated
with gasification alone can be further reduced by 87%. However,
since wood waste requires little upstream processing, the addition
of emission control can effectively reduce the overall health impact
by 59% and the reduction in gasification stage alone would be 88%.
For the effect on ecosystem quality, the main contributions are
from the harvesting and gasification stages as well. With emissioncontrol, gasification only contributes 20% and 12% to the entire life
cycles impact on ecosystem quality for wood waste and pellet,
respectively. Moreover, with emission controls the ecosystem
quality impact for the entire pellet gasification life cycle can be fur-
ther lowered by 32% while impacts associated with gasification
alone can be reduced by 80% when compared to uncontrolled pel-
let scenario.
Lastly,Fig. 4 confirms that the key advantage associated with
switching to woody biomass is the reduction in GHG emissions.
Fig. 4c clearly illustrates that impact on climate change can be re-
duced by 82% and 83% from the current 56.7 kt of CO2-equvalent
per year when wood waste and wood pellets are used, respectively.
Another scenario performance indicator is primary energy con-
sumption. To generate 974 TJ of usable heat annually, the current
natural gas scenario consumes 1284 TJ of primary energy and this
number is slightly higher for the pellet scenarios at 1516 and 1725
TJ for wood waste scenarios. Primary energy takes into account the
energy resource required to produce fuels, power or products.
These include the heating value of raw materials such as harvested
wood and crude oil, energy required to produce fuels such as die-
sel, and energy required to convert different fuels, such as natural
gas or diesel, to electricity.
It is important to acknowledge that human health impact is
more of local concern as compared to theglobal climate change im-
pact. As the UBC district heating systemis located in a densely pop-
ulated area, the stack emissions from the boiler house will have the
most significant impact on human health. The end usage contribu-
tions to human health impact for all five scenarios are normalizedby the base case value andare comparedin Fig. 5. It is apparent that
the human health impact directly linked to the end usage increases
substantially when switched from natural gas to woody biomass as
it would be augmentedby 18- and7.7- folds for uncontrolled wood
waste and pellet gasification, respectively. Thisvalueis lowered to a
133% increase for controlled wood waste scenario and a mere 12%
increase for controlled wood pellet scenario. As a result, it is
strongly recommended that both the PM and NOXemission control
units be installed in biomass combustion/gasification district heat-
ing systems to prevent the deterioration of local air quality and
drastic increase in local health impact, in addition to meeting the
local emission standards. It should be noted that adopting wood
pellet gasification may have other impacts on the community that
are not accounted for in this study, such as the noise and inconve-
nience associated with pellet delivery traffics.
In this study, the gasification plant produces only heat so the
LCA study of a CHP plant in place of the existing boiler house might
yield different results. As UBC also aims to become a net energy
exporter by 2050, the CHP option is readily pursued as UBC has
Fig. 4. Stage-wise impact analysis in terms of (a) human health, (b) ecosystem quality, and (c) climate change for curren t and woody biomass gasification with and without
emission control units.
A. Pa et al. / Bioresource Technology 102 (2011) 61676177 6175
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already decided to establish a CHP demonstration unit on campus
using a system developed by Nexterra and GE to provide green
heat and electricity while serving as a research facility.
4. Conclusions
Replacing fossil fuels with biomass may not always be desirable
and the decision would depend heavily on the priorities of the spe-
cific project. Natural gas combustion outperforms emission-con-
trolled woody biomass gasification scenarios in primary energy
consumption and all impact categories considered other than cli-
mate change while all woody biomass gasification scenarios yield
significant reduction on GHG and external costs. Pellet gasification
is superior to wood waste as it has lower primaryenergy consump-
tion and the health impact associated with stack emission for the
controlled waste wood gasification is 133% higher than the base
scenario, compared to 12% for pellets.
Acknowledgements
The authors would like to thank UBC Sustainability office, UBC
Utility, and Dr. Anthony Lau for providing the air emission data
for the existing natural gas district heating facility. The authors
are also grateful to the financial support from Agriculture Canadas
ABIN program and the UBC Graduate Fellowship (UGF) program.
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