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Cargill High River Fluidized Bed Boiler Offset Project
March 2018
Offset Project Report Form
Cargill High River Fluidized Bed Boiler Offset Project
Project Developer:
Cargill Ltd.
Prepared by:
Blue Source Canada
Reporting Period:
January 1, 2017 – December 31, 2017
Date:
March 7, 2018
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
Greenhouse Gas Assertion
Project Developer:
Cargill Meat Solutions, a division of Cargill Ltd
Sean Murray
472 Ave & Hwy 2A North
High River, AB
(403) 652-8489
www.cargillmeatcsolutions.com
Sean_Murray@cargill.com
Project Documents:
Offset Project Report Form: Cargill High River Fluidized Bed Boiler Offset Project
Offset Project Plan: Cargill High River Fluidized Bed Boiler
Project Plan Date: December 2014, updated April 19, 2016
Quantification Protocol: Quantification Protocol for Energy generation from the Combustion of
Biomass, Version 2.0, April 2014
Project Identification:
Project Title: Cargill High River Fluidized Bed Boiler Offset Project (9327-1871)
Reporting Period: January 1, 2017 – December 31, 2017
Project Description:
The project reduces GHG emissions by displacing off-site fossil fuel generated electricity
emissions and natural gas combustion emissions. The Project consists of the fluidized bed boiler
(FBB) which produces energy fuelled by biomass sourced from bovine by-products and other
compostable plant wastes including meat, pen manure, paunch, dissolved air flotation (DAF) grit,
sludge, tri-canter solids, and specified risk materials (SRM). The FBB generates steam, which
produces electricity on site and displaces natural gas as fuel for process steam requirements.
Project Location: The Project is located at: 12-19-19-28 W4M
Emission Reduction Removal, Sequestration or Capture Assertion:
Vintage Gas Type Quantity (tCO2e)
January 1, 2017 – December
31, 2017
CO2
15,825.00
CH4 17,425.00
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
Vintage Gas Type Quantity (tCO2e)
N2O
-423.00
CO2e -1,170.00
Total Quantity CO2e 31,657.00
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
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Table of Contents
Greenhouse Gas Assertion ..................................................................................................... 2 1.0 Contact Information .............................................................................................. 6 2.0 Project Scope and Site Description .......................................................................... 6
2.1 Project Implementation .......................................................................................... 7 2.2 Protocol ............................................................................................................. 11 2.3 Risks ................................................................................................................. 12
3.0 Project Quantification .......................................................................................... 12 3.1 Summary Table Non-Levied Emissions ................................................................... 12 3.1 Summary Table Levied Emissions and Biogenic CO2 ................................................. 13 3.2 Calculations ........................................................................................................ 13
SS B1 Emissions Collection, Transfer, and Transport ................................................................................ 14 SS B15 Methane Emissions due to Landfill Avoidance .............................................................. 15 SS B6 Emissions Electricity....................................................................................................... 15 SS B18 Displaced On-Site Heat Generation ............................................................................ 16 SS B4 Emissions Fuel Extraction/Processing ....................................................................................... 17 SS P4 Emissions Fuel Extraction/Processing ........................................................................................ 17 SS P12 Emissions Facility Operation .............................................................................................. 17 SS P15 Emissions Combustion of Biomass, Biogas and Fossil Fuels .................................................................. 17 4.0 References ......................................................................................................... 18 Appendix A: Supporting Information ..................................................................................... 19
List of Tables
Table 1: Project Contact Information ...................................................................................... 6 Table 2: Project Information .................................................................................................. 6 Figure 1: Simplified Project Process Flow Diagram .................................................................... 9 Figure 2: Simplified Single Line Diagram ............................................................................... 10 Table 3: Emission factors used for the 2017 Reporting period, (AESRD, March 2015). ................ 14 Table 4: Landfill Design Factors ........................................................................................... 15
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
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1.0 Contact Information
Table 1: Project Contact Information
Project Developer Contact Information
Cargill Ltd.
Sean Murray
472 Ave & Hwy 2A North
High River, AB
(403) 652-8489
www.cargillmeatcsolutions.com
Sean_Murray@cargill.com
Authorized Project Contact
Blue Source Canada ULC
Kelly Parker
1605, 840-7th Avenue SW
Calgary, AB, T2P 3G2
(403) 262-3026 (ext 260)
www.bluesource.com
kellyp@bluesourcecan.com
2.0 Project Scope and Site Description
Table 2: Project Information
Project title Cargill High River Fluidized Bed Boiler Offset Project (9327-1871)
Project purpose and
objectives
The Project is the implementation of a fluidized bed boiler (FBB) fueled
by biomass sourced from bovine by-products and other compostable
plant wastes including meat, pen manure, paunch, dissolved air flotation
(DAF) grit, sludge, tri-canter solids, and specified risk materials (SRM).
The use of bovine by-products as a solid fuel source to the FBB
displaces natural gas demands and electricity sourced from the
commercial grid and, therefore, directly avoids the release of non-
biogenic CO2, CH4, and N2O into the atmosphere as a result of
combustion processes. Furthermore, in the absence of the Project, the
SRMs would have continued to be sent to a landfill for disposal where
varying degrees of anaerobic decomposition may take place and result
in the release of non-biogenic CH4.
Activity start date November 1, 2012
Offset start date May 9, 2013
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
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Offset crediting
period
May 9, 2013 – May 8, 2021
Reporting period
covered by the
project
January 1, 2017 to December 31, 2017
Actual emission
reductions
31,657.00 Tonnes CO2e
Unique site identifier Latitude: 50°37'27.9"N
Longitude: 113°52'41.1"W
LSD: 12-19-19-28 W4M
The Project is located at the Cargill High River Beef Processing Plant in
the northwest quarter of Section 19 (Township Road 19, and Range
Road 28) and 5 km north of the town of High River, Alberta. This is not
an aggregated project.
Project boundary The project boundary includes the entire Cargill Meat Plant, as biomass
is sourced from various areas within the operation.
Specifically, the FBB System includes: the biomass metering bin, natural
gas lines, fluidized bed combustor, storage containers, boiler, steam
turbines, ash storage, fans, stack, and the power lines for electricity
production.
Ownership The Project Proponent is Cargill Ltd., “the Proponent”. The Proponent is
the sole owner of the Cargill High River Beef Processing Plant. All
greenhouse gas reduction benefits resulting from displacing natural gas
and fossil fuel derived electricity from the commercial grid through on-
site heat and power generation are owned by the Proponent.
2.1 Project Implementation
The following changes to the offset project were made in relation to the revised offset
project plan (OPP) dated April 19, 2016 and remain valid to the current reporting period.
i) The project experienced minor communication errors with the low-pressure
steam meter (tag FT-5000) for 12% of total time, between the meter and SCADA
system. These errors were removed from the summation, and metered volume
was assumed to be zero for that day. This is a more conservative approach than
the method listed in the OPP.
ii) Two additional source emissions were added to the quantification methodology
captured under the source P12 – Facility Operations. These source emissions are
the combustion emissions associated with the weekly testing of the emergency
diesel generator and the electricity consumption emissions of two screw pumps
located in the basement of the main facility used to pump the paunch to the FBB
loading area. The diesel generator model is DS500, and while no specifications
could be found on the engine, a genset package for SDS500 by engine
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
Page | 8
manufacturer MTU Onsite Energy was used to approximate the fuel consumption
at 100% power rating of 91 l/hr. The two screw pumps have a power rating of 50
hp and are assumed to run 100% of the year, data provided by Thomas D’Amato,
Process Engineer. This approach is conservative.
iii) The fuel consumption to transport the biomass from site to landfill in the baseline
is not directly measured or reconciled based upon storage volume. As source
emission B1 was an upstream emission that was not directly controlled by the
Proponent, measured data is unavailable. As such, the baseline source emission
B1 is calculated by reconciling the trailer capacity, the measured mass of
biomass, trip distance and fuel efficiency.
iv) A biogas pipeline was tied into the FBB overbed burner to increase the capacity of
the plant to combust the biogas generation from the on-site wastewater
treatment plant. The FBB began to receive biogas on May 14, 2016 mainly on
weekends, experiencing a slow ramp up. Combustion emissions and natural gas
offset from the biogas usage are quantified in source P15 of the FBB offset
project. The avoided venting emissions from the biogas were quantified in the
methane generation waste water offset project, prior to crediting period
completion.
v) Dewatered activated sludge is no longer used in the FBB as the energy content is
too low. This change has no impact on the project.
In 2017, energy associated with the boiler feed water input was included in the
quantification of sources B18 and P15. There is also a new data collection file used for
the Project data sources, titled FBB P&L Tracking Spreadsheet. This file is updated
weekly by personnel at the FBB, from the raw data files. No other changes were made to
the data collection process, record keeping, or emission factors during this reporting
period.
While the current reporting period is unimpacted by recent regulatory changes, the
Project will be required to be updated to the new Protocol in 2019 following the
completion of the carbon levy alignment process with the offset system in Alberta. At
that time, the Project will have to account for levied and non-levied emission reductions
from fuel types impacted by the carbon levy, and levied emissions will be excluded from
the greenhouse gas reduction assertion.
Please see the following pages for the simplified process flow diagram and single line
diagram.
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
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Figure 1: Simplified Project Process Flow Diagram
>>
FBB Offset Project Boundary
MD5B Grid electricity consumed: 1,799,179.00 KwH
Natural Gas: >> 119,656.63 GJ
Biogas: >> 51,088.77 GJ >> Reduced Grid Electricity Import: 623,745.00 KwH
Biomass: >> 527,408.27 GJ >> HP Steam 532,312.70 GJ >> LP Steam: 462,253.76 GJ
BFW: >> 88,638.33 GJ
Efficiency(HHV): 68%
>>
FBB Blowdown: 2%
FBB Turbine Main Plant
Alberta Grid
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
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Figure 2: Simplified Single Line Diagram
FBB Generator
>>
<<
Dir
ecti
on
al O
verc
urr
ent
REL
AY
<>
<>
>
<
<<
GRID
MDP-5B1: FBB Building load & emergency generator
FBB Equipment
Meter: MDP-5B2
Meter: MDP-5B
MDP-5A: Main Plant
Meter: MDP-5
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
Page | 11
2.2 Protocol
The Project was implemented under the Quantification Protocol for Energy Generation
from the Combustion of Biomass Waste, version 2.0, April 2014. Only one protocol was
used to develop this Project.
The Protocol was applicable to the Project because the use of bovine by-products as a
biomass fuel source to the FBB displacing natural gas demands and electricity sourced
from the commercial grid. Therefore, the Project directly avoided the release of non-
biogenic CO2, CH4, and N2O into the atmosphere as a result of combustion processes. In
the absence of the Project, the SRMs would have continued to be sent to a landfill for
disposal where varying degrees of anaerobic decomposition may take place and result in
the release of non-biogenic CH4.
Therefore, the Project met the Protocol requirements as follows:
• Eligible agricultural processing and residues (such as food processing wastes,
paunch, etc.) biomass feedstocks were used in the Project
• The project diverted feedstocks, such as SRM, from landfill
• The biomass was combusted to produce heat or electricity in a thermal energy
system
• Energy generated from the combustion of biomass waste offset fossil fuel-based
energy
• Emissions from the Project were less than those that would have occurred in the
absence of the Project, and
• The reductions achieved by the Project were based on actual measurement and
monitoring
As the activities of the Project were applicable under the Protocol and the displacement
of fossil fuels with biomass was not an industry standard, the results of this Project were
considered additional and would not have occurred under business as usual
circumstances.
Flexibility Mechanisms:
The quantification of GHG emission reductions for the Project uses the following
flexibility mechanisms as outlined in section 1.3 of the Protocol:
Flexibility (1): Diversion of biomass waste from baseline disposal in a landfill. The
project developer must be able to demonstrate that the waste stream was being
disposed of in a landfill for a period of three years prior to project initiation (see
section 5.1.2 for minimum disposal requirements).
Because the SRM was combusted in the FBB system rather than sent to landfill and
decomposed, this flexibility mechanism was used to capture the emission reduction from
avoided landfill methane generation. The Project met the minimum record requirements
for documentation of the baseline electricity use via invoicing, as well as the records
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
Page | 12
requirements from the waste management facilities to claim landfill diversion methane
avoidance credits from landfill records and waste tracking records.
Flexibility (5): Projects can use an energy-based approach to estimate biomass fuel
consumed. If this approach is being used, the project developer must be able to
measure, monitor, and record the energy flow of all streams into and out of the
biomass combustion unit to generate an accurate energy balance for the project.
Energy-based combustion emission factors for biomass and fossil fuel combustion
are applied to quantify emissions for each stream and to quantify GHG emission
reductions.
The Project employed an energy-based approach to estimate the biomass fuel consumed
in the project condition as described above and illustrated in Figure 1. It utilized the
energy-based combustion emission factor as published in the IPCC 2006 Guidelines for
National Greenhouse Gas Inventories, Volume 2 Energy (International Panel on Climate
Change, 2006) to quantify emissions from biomass combustion. However, mass-based
values will be used for the quantification of Flexibility mechanism 1.
Flexibility (6): Site-specific emission factors calculated on the basis of fuel analysis
are preferred and must be used when available. If site-specific factors cannot be
obtained, emission factors from Environment Canada or equivalent must be used.
The Project employed a combination of default emission factors from Alberta
Environment and Sustainable Resource Development (AESRD, 2015), as well as site
specific emissions factors where available.
While this Protocol is flagged as part of the Carbon Levy Alignment process, this is an
ongoing Project and does not require authorization from the Director to quantify. Finally,
deviation requests were not initiated or required for this Project.
2.3 Risks
Risks associated with the offset Project have been included and discussed in Table 2 of
the offset project plan, and no additional risks have been identified during this reporting
period. No other offset project exists at the LSD 12-19-19-28 W4M at this time.
3.0 Project Quantification
3.1 Summary Table Non-Levied Emissions
Vintage Gas Type Baseline
Emissions
Project
Emissions
Total
Reduction,
Sequestration,
or Capture
2017 CO2 22,287.67 6,461.98 15,825.00
2017 CH4 21,330.73 3,905.08 17,425.00
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
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2017 N2O 151.87 575.41 -423.00
2017 CO2e 399.20 1,569.54 -1,170.00
Total for
Reporting
Period
CO2e 44,169.46
tCO2e
12,512.01
tCO2e
31,657.00
tCO2e
Table “3.1 Summary Table Levied Emissions and Biogenic CO2” below is excluded for this
report, as levied emissions and biogenic CO2 are not applicable to this project for vintage
2017. Following the release of the new offset protocols to align with the carbon levy, this
project will be updated in 2019 to exclude levied emission reductions from the offset claim
and abide with the new protocol. However, only non-levied emissions have been reported,
as indicated above, for this reporting period.
3.1 Summary Table Levied Emissions and Biogenic CO2
Vintage1 Gas Type2 Baseline
Emissions
Project
Emissions
Total
Reduction,
Sequestration,
or Capture
2017 CO2 n/a n/a n/a
2017 CH4 n/a n/a n/a
2017 N2O n/a n/a n/a
2017 Other
(specify)
n/a n/a n/a
2017 Biogenic n/a n/a 0 tCO2
Total 2017 CO2e 0 tCO2e 0 tCO2e 0 tCO2e
Total for
Reporting
Period
CO2e XX tCO2e XX tCO2e XXtCO2e
3.2 Calculations
GHG emission reductions were calculated following the Quantification Protocol for Energy
Generation from the Combustion of Biomass wastes, version 2.0 April 2014. The
activities and procedures outlined in the Offset Project Plan provide a detailed
description of the project’s adherence to the requirements of the quantification protocol.
The formulas used to quantify greenhouse gas offset by the project are listed below.
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
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EmissionReduction = EmissionsBaseline – EmissionsProject
EmissionsBaseline = sum of the emissions under the baseline condition
= Emissions from Collection, Transfer and Transport of Biomass (B1)
+ Emissions from Biomass Disposal (B15)
+ Emission from Displaced Off-site Electricity Generation (B6)
+ Emission from Displaced On-site Heat Generation (B18)
+ Emission from Fuel Extraction and Processing (B4)
Emissions Project = sum of the emissions under the project condition.
+ Emissions from combustion of biomass, biogas and fossil fuels (P15)
+ Emissions from facility operation (P12)
+ Emissions from fuel extraction and processing (P4)
Table 3 provides the emission factors used for the project. A site specific natural gas
combustion CO2 emission factor is used for sources P15 and B18.
Table 3: Emission factors used for the 2017 Reporting period, (AESRD, March
2015).
Parameter Relevant
SS
CO2 Emission
Factor
CH4 Emission
Factor
N2O Emission
Factor
Electricity
Generation
B6, P12 0.59 tonnes
CO2e/MWh
- -
Electricity
Consumption
B6, P12 0.64tonnes
CO2e/MWh
- -
Natural gas
combustion
P15, B18 2.03 kg/m3 0.037 g/m3 0.035 g/m3
Natural Gas
Extraction
P4 0.043 kg/m3 2.3 g/m3 0.004 g/m3
Natural Gas
Processing
P4 0.090 kg/m3 0.3 g/m3 0.003 g/m3
Diesel Combustion B1 2663 g/l 0.133 g/l 0.4 g/l
Diesel Production B4 0.138 kg/l 0.0109 0.000004 kg/l
SS B1 Emissions Collection, Transfer, and Transport
SSB1 = Fossil Fuel for Transport × EFtransport × 10−6
(1)
= 637.94 tCO2e
Where:
Fossil Fuel for Transport =MBiomass
Truck Capacity× Transport Distance × Truck Fuel Efficiency
(2) = 229,020.50 litres
And:
EFtransport = Product Transport Emission Factors, g CO2e/l
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
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Truck fuel Efficiency = 39.5 l/100 km (NRCAN, 2013)1
Transport Distance = 750 km round trip
SS B15 Methane Emissions due to Landfill Avoidance
QCH4,t = ∑ [k × (MSRM − MASH) × Lo × e−k(t−1) × (1 − Ox)]t=40t=1 × (1 − R) (1)
=
Equation 1 is used in conjunction with Table 4 to determine the emissions from avoided
biomass disposal.
Table 4: Landfill Design Factors
Design factor Notation Value
Methane Correction Factor MCF 1
Degradable Organic Carbon DOC 0.17
Fraction of Degradable Organic Carbon Dissimilated DOCF 0.5
Fraction of CH4 in Off gas from Disposal Site F 0.5
Recovered CH4 at Disposal Site R 0
Oxidation factor Ox 0.1
30 yr Annual Average Precipitation (mm/yr) – Brownfield, AB PCPN 470
SS B6 Emissions Electricity
Emissions of CO2e = max(Egenerated,project − Econsumed,project − Egenerated,historic,adjusted, 0) ×
EFP
= 399.20 tCO2e
Where:
Egenerated,project = electricity generated by the Project, kWh;
Econsumed, project = electricity consumed by the Project, kWh;
Egenerated, Historic, adjusted = Historic electricity generated on site scaled to meet current
production, kWh. This term will always be zero for the Project as previously no
electricity was generated on-site.
1 The fuel efficiency for heavy duty trucks may be updated following the phase-in of
Environment Canada’s proposed Heavy Truck GHG Emission Standards as it applies to the
Project.
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
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EFP (tonnes CO2e/kWh) =Emission factor for on-site renewable electricity
production
SS B18 Displaced On-Site Heat Generation
The avoided emissions from displacing natural gas used in the baseline occur through the
distribution of low pressure steam to the Cargill High River Plant. The low-pressure steam
generation is calculated using the methods as outlined below:
E𝐵18 = VNG,eq × EFNG,i (7)
= 20,438.12 tCO2e
Where:
VNG,eq = Equivalent volume of natural gas displaced by thermal energy production, e3m3 EFNG,i = Natural Gas Combustion emission factor for GHG species, i, tonnes/e3m3 i = CO2, CH4, N2O gas species
And:
𝑉𝑁𝐺,𝑒𝑞 = (𝑄𝐿𝑃 − QBFW) ÷ EfficiencyNG−Boiler ÷ 𝐻𝐻𝑉𝑁𝐺 (8)
= 9,931.07 e3m3
Where:
QLP = Energy of Low Pressure steam produced, GJ QBFW = Energy of boiler feed water input, 76,797 GJ HHVNG = higher heating value of natural gas, MJ/m2 EfficiencyNG-Boiler
3= Boiler efficiency of pre-existing natural gas boiler, %
Where:
𝑄𝐿𝑃 = 𝐻𝐿𝑃 × 𝑀𝑆 = 400,438.67GJ (9)
And: HLP = Enthalpy of low pressure steam, BTU/lbm,
MS = Mass flow rate of steam, klbs
The enthalpy of the steam at the specific temperature and pressure can be found using
steam tables, or as in this case, calculated through the Excel add in: WINSTEAM 4.0.
If (𝐻𝑔𝑝𝑟𝑜𝑗 − 𝐻𝑐,𝑝𝑟𝑜𝑗) > 0,
where: Hg,project = thermal heat generated by the project, GJ Hc,proj =(HHP – HLP) =Thermal heat energy used by the project, internal heat loss in the
system, GJ
then the heat generated by the project must be compared to the average adjusted historic
heat generation over a 3 year period scaled to current operations. As this is a newly
constructed facility, a natural gas baseline is assumed, and the historic heat generated is
equivalent to the project heat generation.
3 HHV was used as the boiler efficiency of Saskatoon boiler was calculated using HHV values
Cargill High River Fluidized Bed Boiler Offset Project
March 2018
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SS B4 Emissions Fuel Extraction/Processing
ENGXP = ∑ VNGeq × EFNXP𝑖 (10)
=2,175.66 tCO2e
Where:
EFNXPi= Emission factor for natural gas extraction and processing, i= CO2, CH4, and
N2O, tonnes/e3m3
SS P4 Emissions Fuel Extraction/Processing
Extraction and Processing Emissions = ∑ ( V𝑗 × XPi)𝑗𝑖 (13)
=588.25 tCO2e
Where:
XP = extraction and processing emission factors
i = CO2, CH4, N2O gas species
j = fossil fuel: diesel, natural gas
SS P12 Emissions Facility Operation
Emissions, i = ∑ ((𝑉𝐷𝑇+𝑉𝐺𝐸𝑁𝑆𝐸𝑇) × EFDiesel,i)𝑖 + (FBBGrid × EFC) (11)
=1625.86 tCO2e
Where:
FBBGrid = Electricity required to operate the primary and auxiliary electrical
equipment located in the boiler building, MWh;
EFC = Emission factor for grid electricity consumption, see table 3
SS P15 Emissions Combustion of Biomass, Biogas and Fossil Fuels
Combustion Emissions, P15 = Natural Gas Combustion + Biogas Combustion + Biomass
Combustion
Natural Gas Combustion Emissions = ∑ ((𝑉𝑁𝐺) × EF𝑁𝐺,𝑖)𝑖 (12)
=10,297.90 tCO2e
Where:
VNG = total volume of natural gas required for start-up of the under-bed
burner, and supplementary gas for the over-bed burner when required, e3m3;
EF NG, i = natural gas combustion emission factor for industrial processes of
specified greenhouse gas species , i
i = CO2, CH4, N2O gas species
Biomass Combustion Emissions = ∑ (Energy HP Steam−QTOTAL,IN
𝜂𝐹𝐵𝐵) × EF𝐵,𝑖𝑖 (13)
Cargill High River Fluidized Bed Boiler Offset Project
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Where:
ENERGY HP STEAM = high pressure steam energy produced (energy output), GJ
EFB, i = CH4 and N2O emission factors for the combustion of biomass,(CO2
emissions are biogenic and excluded from the quantification) tonne/GJ
ƞFBB = FBB efficiency, 68%
QTOTAL, IN = total energy input to FBB, GJ
And:
QTOTAL, IN = QNG + QBIOGAS +QBFW
Where:
QNG = energy of natural gas used in the FBB, GJ
QBiogas = energy of the biogas used in the FBB, GJ
QBFW = energy of the boiler feed water, GJ
Biogas Combustion Emissions = ∑ ((𝑉𝐵𝐺) × EF𝑁𝐺,𝑖)𝑖 (14)
Where:
VBG = volume of biogas sent to FBB, e3m3
EFNG,I = CH4 and N2O emission factors for the combustion of natural gas,
assumed to be representative of the biogas (CO2 emissions are biogenic and
excluded from the quantification), tonne/e3m3
4.0 References
Alberta Environment, 2014. Quantification Protocol for Energy Generation from the Combustion of
Biomass Waste, version 2.0, April 2014.
Environment Canada, 2016, National Inventory Report 1990-2014: Greenhouse Gas Sources and
Sinks in Canada. Environment Canada, Ottawa.
Gas Processors Association, 2009, GPA Standard 2145-09: Table of Physical Properties for
Hydrocarbons and Other Compounds of Interest to the Natural Gas Industry. GPA, Tulsa.
Alberta Environment and Sustainable Resource Development. (March 2015). Carbon Offset Emission Factors
Handbook, version 1.0. Edmonton: Government of Alberta.
IPCC. (2006). Stationary Combustion . Guidelines for National Greenhouse Gas Inventories. IPCC.
NRCAN. (2013, 11 18). Fuel Efficiency Benchmarking in Canada's Trucking Industry. Retrieved 12 17, 2014, from
Natural Resources Canada: http://www.nrcan.gc.ca/energy/efficiency/transportation/commercial-
vehicles/reports/7607
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Appendix A: Supporting Information
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