cargill high river fluidized bed boiler offset project · january 2019 page 6 of 50 version 2.0...

Cargill High River Fluidized Bed Boiler Offset Project

January 2019

Version 2.0 Project Plan Template – July 2018

Offset Project Plan Form:


Project Developer:

Cargill Ltd.

Prepared by:

Blue Source Canada ULC

Date:

January 29, 2019


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Version 2.0 Project Plan Form – July 2018

Table of Contents

1.0 Contact Information .............................................................................................. 4 2.0 Project Scope and Site Description .......................................................................... 4

2.1 Project Description ................................................................................................ 6 Conditions Prior to Project Initiation ........................................................................ 8 Description of How the Project will Achieve GHG Emission Reductions/Removals ........... 8 Project Technologies, Products, Services and the Expected Level of Activity .................. 9

2.2 Protocol ............................................................................................................. 12 Relevant Quantification Protocol ............................................................................ 12 Protocol Applicability ............................................................................................ 13 Protocol Justification ............................................................................................ 13 Flexibility Mechanisms ......................................................................................... 14

2.3 Risks ................................................................................................................. 14 3.0 Project Quantification .......................................................................................... 16

3.1 Inventory or Sources and Sinks ............................................................................ 16 Justification for excluding sources and sinks ........................................................... 16 Quantification variances since first reporting period ................................................. 17 Quantification of Source and Sinks ........................................................................ 19

3.2 Baseline and Project Condition .............................................................................. 21 Baseline Condition ............................................................................................... 21 Project Condition ................................................................................................. 21

3.3 Quantification Plan .............................................................................................. 21 Net Emissions Reductions ..................................................................................... 21 Offset Eligible Reductions ..................................................................................... 25 Levied Emissions Reductions ................................................................................. 25

3.4 Monitoring Plan ................................................................................................... 25 3.5 Data Management System.................................................................................... 27

Data Management and QA/QC at Cargill Meat Solutions ........................................... 27 Data Management and QA/QC at Bluesource .......................................................... 29 Back-up Procedures at Bluesource ......................................................................... 30 Document Retention Policy at Bluesource ............................................................... 31

4.0 Project Developer Signature ................................................................................. 32 5.0 References ......................................................................................................... 33 Appendix A: Supporting Information ..................................................................................... 34 Appendix B: Cargill Data Management Plan (All Metrics) ......................................................... 36 Appendix C: FBB Plant Load List ........................................................................................... 40 Appendix D: Approval Letter for Historic Crediting .................................................................. 47 Appendix E: IT Backup Procedure for Bluesource .................................................................... 48 Appendix F: Document Retention Policy at Bluesource ............................................................ 49

List of Figures

Figure 1: Project Location...................................................................................................... 5 Figure 2: The FBB Building at Cargill High River ....................................................................... 7 Figure 3: Main Project Elements ............................................................................................. 7 Figure 4: Simplified PFD of Cargill High River, pre-project ......................................................... 8 Figure 5: Simplified PFD of Cargill High River, post-project ........................................................ 9 Figure 6: Typical Generator Efficiency, extracted from Test Report No. H-S1000211 ................... 12


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Figure 7: Process flow diagram for the project condition of biomass to energy (Alberta Environment

and Sustainable Resource Development, June 2018) ............................................... 16 Figure 8: Quantification Calculator Data Flow ......................................................................... 30

List of Tables

Table 1: Project Contact Information ...................................................................................... 4 Table 2: Project Information .................................................................................................. 4 Table 3: Cargill FBB Risk Analysis ......................................................................................... 14 Table 4: Appended Data Parameters to the Monitoring Plan ..................................................... 18 Table 5: Emission factors used for the Project. ....................................................................... 20 Table 6: Sample Monitoring Plan .......................................................................................... 25 Table 7: Cargill Data Management Plan – FBB Offset Project Data Collection .............................. 27 Table 8: Metering maintenance and calibration details ............................................................ 28 Table 9: Heat Production and Miscellaneous Building Equipment .............................................. 41 Table 10: Fuel Production Equipment: SRM System ................................................................ 43 Table 11: Fuel Production equipment: Paunch System ............................................................ 44 Table 12: Feedstock Transmission Equipment ........................................................................ 46


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1.0 Contact Information

Table 1: Project Contact Information

Project Developer Contact Information Additional Contact Information

Cargill Meat Solutions, a division of Cargill

Ltd

Cargill Meat Solutions, a division of Cargill

Ltd

Thomas D’Amato Thomas D’Amato

472 Ave & Hwy 2A North 472 Ave & Hwy 2A North

High River, AB High River, AB

(403) 652-4688 Ext. 216 (403) 652-4688 Ext. 216

www.cargillmeatsolutions.com www.cargillmeatsolutions.com

Thomas_D'[email protected] Thomas_D'[email protected]

Authorized Project Contact (if applicable)

Blue Source Canada ULC

Justin Friesen

1605, 840-7th Avenue SW

Calgary, AB, T2P 3G2

(403) 262-3026 (ext 301)

www.bluesource.com

[email protected]

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. Emissions

offsets are generated by the Project through diversion of waste biomass

from landfill disposal. In the absence of the Project, the SRMs would have

http://www.cargillmeatsolutions.com/

http://www.cargillmeatsolutions.com/


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continued to be sent to a landfill 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 crediting

period

May 9, 2013 – May 8, 2021

Estimated emission

reductions/

sequestration

Estimated total greenhouse gas emission reductions expected from the

project in the offset crediting period: 238,308 tCO2e

Estimated annual greenhouse gas emission reductions expected from the

project in the offset crediting period: 29,788 tCO2e

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.

Is the project located

in Alberta?

Yes

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. Figure 1 shows the project’s location.

Figure 1: Project Location


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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.

Bluesource Canada ULC. Has the right to sell the emission offsets,

indicated by an agency contract between Cargill Ltd. and Bluesource

Canada ULC.

2.1 Project Description

The Cargill High River Beef Processing Plant (herein referred to as ‘the Plant’) began

operations in 1989. The Plant consists of holding pens, and houses facilities for animal

slaughter, cutting, packaging and freezing, rendering of non-consumable materials, hide

curing, and wastewater treatment. Approximately 4,500 cattle heads are processed per day

at the facility.

In 2010 the Canadian Food Inspection Agency (CFIA) implemented a feed ban rule (CFIA,

2010) on the beef industry in Canada, with the purpose of eliminating bovine spongiform

encephalopathy (BSE) (or "mad cow disease") in Canada. The feed ban rule prohibits the

inclusion of SRMs in animal feeds, pet foods, and fertilizers, and therefore SRMs now have to

be sent to specialised landfill sites, which is costly for beef processors like the Proponent.

In response to this challenge the Proponent developed a strategy to alleviate high waste

disposal costs through the construction of a fluidized bed boiler (FBB). The FBB would reduce

the Plant’s waste by utilizing both compostable wastes and SRMs as fuel to displace a portion

of the electricity load and process steam requirements through on-site generation. The FBB

project was approved by both Alberta Environment (Approval 683-03-00, dated March 31,

2011) and the Alberta Utilities Commission (Approval No U2011-400, dated November 9,

2011).

Combusting the SRMs as fuel provides a safer and more economically and environmentally

effective means of treatment and removal of SRMs compared to the previous method of

landfill disposal. The Proponent has implemented the process of accumulating and storing

bovine by-products, DAF fines, tricanter solids, and dewatered activated sludge for use as a

solid fuel in the FBB. In this Project, the paunch, pen manure, dewatered activated sludge,

tricanter solids, DAF fines, and SRM are collectively identified as "biomass".

The Proponent collects, dewaters and combusts the biomass in an FBB system to produce

high pressure steam in a water-tube boiler. This steam then passes through a back pressure

turbine and produces a portion of the base electrical load for the facility. The reduced pressure

steam leaving the turbine is then captured and used in the Plant’s production processes.

Based on calculations performed by the Proponent, it has been estimated that approximately

12% of the Plant’s electrical load and 60% of the Plant’s steam load will be supplied by the

biomass feedstock. As a result, the use of the biomass as a solid fuel feedstock will directly

offset the demand for natural gas and electricity sourced from the commercial distribution

grid at the Plant.

Figure 2 shows the project building.


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Figure 2: The FBB Building at Cargill High River

A simple diagram of the FBB system is included as Figure 3.

Figure 3: Main Project Elements


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Conditions Prior to Project Initiation

Figure 4 illustrates the conditions before the FBB project was implemented.

Figure 4: Simplified PFD of Cargill High River, pre-project

As illustrated, prior to the Project, the Proponent disposed of their waste streams as follows:

• Compostable materials, including paunch, pen manure, DAF fines, dewatered

activated sludge, and tricanter solids, were sent to the Roseburn Ranch Feedlot and

Tongue Creek Composting Ltd. (near High River) where the materials were

composted;

• Meat, bone, blood, and fat were rendered on site;

• SRMs were sent for disposal at an approved landfill in Alberta, Coronation Landfill,

which is located near the Town of Coronation, AB - approximately 3.5 – 4 hour drive

from High River.

The rendering, slaughter, and fabrication processes at the Plant were dependent on fossil fuel

derived electricity (sourced from the Alberta Electricity Grid) and natural gas as fuel to

produce process steam.

Description of How the Project will Achieve GHG Emission Reductions/Removals

Figure 5 illustrates the conditions after the implementation of the FBB project.


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Figure 5: Simplified PFD of Cargill High River, post-project

As a result of the implementation of the Project, direct GHG emission reductions will occur as

follows:

• First, averting the SRM from landfill disposal directly avoids the release of non-biogenic

CH4 emissions from anaerobic decomposition;

• Second, a reduction in natural gas consumption for steam production avoids non-

biogenic emissions related to the combustion of natural gas including CO2, CH4, and

N2O;

• Third, reducing the consumption of grid electricity results in the avoidance of grid

transmission and distribution emissions;

• Fourth, processing the waste streams on-site reduces emissions associated with

transportation to off-site disposal.

The FBB produces steam and electricity for normal operations during the day and is either

reduced to a minimum output or is taken off-line overnight and on weekends for cleaning and

proper maintenance processes. The implementation of the FBB does not affect the Plant’s

capacity. On average, the Proponent expects to feed 21,000 lb/hr (for a total of 21 hours per

day) of biomass to the FBB and produce 57,000 lb/hr of steam at 650 psia. Of the total

electricity produced, the Plant is expected to consume 1.4 MW.

Project Technologies, Products, Services and the Expected Level of

Activity

The waste materials used as solid fuel in the FBB process are separated into two streams to

isolate the SRM:

(i) SRMs; and/or


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(ii) DAF grit, meat, paunch, manure, tricanter solids (crax), and dewatered activated

sludge1.

Typical SRM waste streams consist of the tissues of ruminant animals that may have high

concentrations of BSE prions including the brain, skull, eyes, spinal cord, vertebral column,

dorsal root ganglia and tonsils and distal ileum of the small intestine. SRMs must be isolated

and tracked from point of origin to destruction to mitigate the risk and exposure of bovine

spongiform encephalopathy. If the streams were mixed, then the secondary stream would

also be classified as SRM waste.

The SRM waste stream and the biomass stream from process upsets are stored in the FBB

room in two separate storage bins with each bin undergoing different grinding and sizing prior

to combustion. Natural gas is used as a start-up fuel for the FBB. As soon as the waste streams

ignite, the FBB can then be solely fuelled by the continued addition of the Plant’s waste

streams.

As shown in Figure 3: Main Project Elements, the SRM and non-SRM raw materials are fed

separately by an automated conveyor system into the gasification zone of the FBB.

Temperature, pressure, air velocity of the bed and the gas zones are monitored. The air

velocity is predominantly influenced by the induced draft fan at the end of the system. Most

of the raw materials entering the gasification zone are incinerated before reaching the

fluidization zone. The remaining material becomes fluidized in the fluidization zone and rise

to sufficient temperatures where they are ignited, converting all of the organic material into

ash. Ash produced in the process will then enter the gasification zone. An automated control

system in the fluidized bed zone will permit other fuels to enter in order to maintain an

adequate combustion temperature. Scorched raw materials act as the fuel to maintain

combustion temperatures of 913°C in the gasification zone. The Plant has implemented

safeguards to ensure that the zone is maintained above this temperature including a system

alarm and, where needed, the system will either shut down or activate a secondary burner

that is fuelled by natural gas.

Hot gases pass through a water tube boiler and steam is produced. Before entering the ash

collection system, the gas is further reduced in temperature. In the ash collection system, the

gas passes through an industrial grade bag filter where the ash is collected and transferred

to a holding chamber and subsequently hauled for disposal.

In order to ensure that the SRM undergoes complete combustion, the gasification zone of the

FBB is maintained at 913°C or higher and the retention time of the material is held for a

minimum of four seconds. The retention time is determined by the volume and velocity of the

gas in the gasification zone. It is anticipated by the Proponent that the temperature and

retention time will meet the CFIA regulations in regards to SRM destruction, and once

approved in the future, the Proponent may sell the produced ash off-site for use as concrete

additive. Currently, these conditions have not been confirmed to meet CFIA specifications for

SRM destruction, and the ash produced through the incineration process is transported to the

Paintearth Resource Recover Center (Coronation Landfill) designated for SRM disposal with

EPEA Approval number 70686-01-00. Emissions from disposal, transport and decomposition

of the ash is excluded from the quantification methodology as the Protocol dictates.

1 Note that some of the biomass sources in the secondary waste stream are only introduced

to the FBB as a result of process upsets. Under normal operations, these will NOT be present

in the fuel stream.


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The high pressure steam produced by the above process passes through either a 1.4 MW

turbine generator, or pressure reducing valve, with subsequent low pressure steam directed

to meet steam demand during rendering, slaughter, and fabrication processes in the Plant.

High pressure steam produced at the boiler is reduced in pressure and temperature and

redirected to an existing steam header.

Below is an explanation of the project specific technologies, products, and services as a result

of implementing the FBB at the Cargill High River Beef Processing Plant. Electricity

consumption from the operation of the project equipment is captured under the project

emission source, Facility operations.

2.1.3.1 Project Technologies and Services

(i) Boiler Building

The boiler building is 12,640 ft2 and was constructed to house the boiler. Although the

building is constructed as a separate structure to the main Beef Processing Plant, it is

connected to existing plant infrastructures including water, wastewater system, steam,

paunch collection, condensate and air piping. The boiler building includes a PLC room and

the FBB boiler room is an enclosed, self-contained facility. Solid feedstocks that are above

the regulated size are recycled back into the SRM raw material bin. In addition, the

following equipment is installed as a component of the FBB:

• FBB combustor;

• Forced Draft (FD) fan;

• boiler;

• economizer;

• Induced Draft (ID) fan;

• stack;

• fuel metering bin;

• ash handling system including storage silo;

• bed material handling system;

• limestone injection system.

The boiler has a steam generation capacity of 65,000 lbs/hr of steam with a calculated

efficiency of 68%.

(ii) Hoppers

Two hoppers, or storage bins, are installed in the fuel portion of the boiler building and

contain waste materials that are used as fuel for the FBB. The hoppers are metal storage

bins located within the Boiler Building, below grade, and enclosed by concrete walls and

flooring. One hopper contains the SRM feedstock and the other all non-SRM feedstocks.

(iii) Conveyor System

Conveyor systems transport the waste from the hoppers and storage bins to the FBB for

combustion. The conveyor is completely contained and equipped with screening and

drainage systems.

(iv) Paunch Press


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The paunch press is housed within the Boiler Building. Prior to combustion, the paunch is

mechanically dewatered to ensure a sufficient energy level is maintained by the material.

(v) Feedstock PreBreakers

The Plant uses a Svaertek 30x60 grinder (i.e. a rotational grinder) to breakup the SRMs

into 1 in2 cubes. The intention of producing 1”x 1” cubes is to maximize the surface area

of the SRMs as a fuel source. Non-SRM materials are ground using an industrial grade

chipper and a target size of < 3 in2. Based on the available energy content, the non-SRM

materials do not require as fine of a grind to facilitate combustion as compared to the

SRMs.

(vi) Generator

The generator is an 1800 RPM, 60 Hz, 3 phase Marathon Electric MagnaPower, model

number: 1020FDM1211. The typical generator efficiency runs from a minimum of 92% to

97% and depends upon the kW output, as seen in Figure 6. The generator is run weekly

for 1 to 2 hours to ensure proper operation, to account for its diesel consumption 9.1L/hr

is assumed (based on specification for running at maximum power).

Figure 6: Typical Generator Efficiency, extracted from Test Report No. H-S1000211

2.2 Protocol

Relevant Quantification Protocol

The quantification protocol used is the Quantification Protocol for Energy Generation from the

Combustion of Biomass Waste, Version 2.2 (Alberta Climate Change Office, June 2018)

published by Alberta Climate Change Office (ACCO) ('the Protocol').

ACCO released a memorandum on April 6, 2018 specifying protocols that have been updated

and requirements for currently registered offset projects to update to the new protocols no

later than January 1, 2019. The protocol updates were part of a process to align the offset


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system with the carbon levy. Accordingly, the Project’s offset project plan has been updated

to version 2.2 of the protocol, however, it is only applicable to Project reporting periods from

January 1, 2019 onwards as specified by ACCO. As such, any Project credits generated for

earlier reporting periods but submitted after January 1, 2019 will continue to use the previous

offset project plan utilizing protocol version 2.0.

In addition to the Protocol, the Carbon Emission Factors Handbook (Alberta Environment and

Sustainable Resource Development, March 2015) is also a reference in the quantification. This

Handbook is intended to be updated annually by AEP to reflect the latest emission factors

published by the National Inventory Reports and best practices. If the Handbook reflects out

dated information it is the best practice of Bluesource Canada (“Bluesource”) to use the most

up-to-date published values as in the National Inventory Report, or other publications.

Protocol Applicability

The following section provides the reasoning for the applicability of using the Protocol.

1. The project biomass waste is one of the listed eligible biomass waste types in Table 1

of the Protocol: Agricultural processing residues (e.g. Food processing);

2. The biomass waste is combusted to produce heat and electricity in an advanced energy

system (e.g. using gasification in a Fluidized Bed Boiler);

3. Energy generated from the combustion of waste biomass partially offsets fossil fuel

based energy from reducing the Plant’s reliance on imported grid electricity and natural

gas boilers used to generate low pressure steam for the plant;

4. The emissions from the bio-energy production are less than would have occurred in

the absence of the project;

5. The Project is eligible for additional crediting opportunity for changes in disposal

practice from landfilling as proof of historical practice exists;

6. Reductions achieved from the project are based on actual measurement and

monitoring as indicated by the proper application of this protocol; and

7. The Project meets the offset system eligibility criteria specified in the Carbon

Competitiveness Incentive Regulation (CCIR), standards and guidance documents for

the Alberta Offset System.

8. The Project quantifies, tracks and reports emissions from fossil fuels that are subject

to the Alberta Carbon Levy (i.e. thermal energy displacement and natural gas

consumption) but does not include these emissions as eligible emissions offsets. This

approach meets the requirements of the Protocol’s carbon levy alignment.

Protocol Justification

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.

Emissions offsets are generated by the Project through diversion of waste biomass from

landfill disposal. In the absence of the Project, the SRMs would have continued to be sent to

a landfill where varying degrees of anaerobic decomposition may take place and result in the

release of non-biogenic CH4.


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As the activities of the Project are applicable under the Protocol and the displacement of fossil

fuels with biomass is not an industry standard, the results of this Project are 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 1.4 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

records requirements.

The Project meets the records requirements from the waste management facilities to

claim landfill diversion methane avoidance credits from landfill records and waste tracking

records.

Flexibility (3): 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 employs an energy based approach to estimate the biomass fuel consumed

in the project condition as described above, and utilize 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.

2.3 Risks

Specific risks to this Project include Protocol risks, regulatory risks, and Project risks as listed

in Table 3: Cargill FBB Risk Analysis

Table 3: Cargill FBB Risk Analysis

Risk

Category

Risk Mitigation/

Explanation

Severity Likelihood Risk Level

Regulator

y

In the event

provincial and/or

federal regulations

are created to

mandate a portion

of the heat and

power at meat

processing plants to

be produced by

biomass the project

may be deemed to

No such

provincial or

federal

regulations

have been

drafted or are

anticipated.

Severe Unlikely Low


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Risk

Category

Risk Mitigation/

Explanation

Severity Likelihood Risk Level

no longer be

additional.

Project

Risk

Market forces may

hinder the

continued

operations and

maintenance of the

biomass to energy

facility as a result of

cheaper forms of

fossil-fuel derived

energy and/or

disposal of biomass

becoming more

economically

attractive than the

project.

This is unlikely

to prevent the

operation of the

Project as

Cargill has

invested

significant

capital in the

Project;

furthermore,

the fuel and

waste disposal

functions of the

project are now

effectively free.

Moderate Unlikely Low

Technical

Risk

Technical risks may

include the use of

waste materials that

exhibit low energy

content (e.g.

deactivated sludge,

water-saturated

materials, etc.) and

may require more

energy to process

and incinerate than

the energy it

produces.

The Plant is

configured to

ensure that the

energy content

of the feedstock

is maintained at

a desirable level

by utilizing

waste streams

with a higher

energy content.

Moderate Unlikely Low


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3.0 Project Quantification

3.1 Inventory or Sources and Sinks

The Protocol contains a list of baseline and project sources and sinks (SSs) that were deemed

applicable for projects developed according to the protocol. The SSs for the project are

identified in Figure 7: Process flow diagram for the project condition of biomass to energy

(Alberta Environment and Sustainable Resource Development, June 2018).

Figure 7: Process flow diagram for the project condition of biomass to energy

(Alberta Environment and Sustainable Resource Development, June

2018)

Justification for excluding sources and sinks

Those sources and sinks (SSs) that are not applicable will be excluded as their input variables

will be zeros. As such, the project developer can exclude sources and sinks that are not

applicable to their project with reasonable justification. The following SSs have been excluded

from quantification:

SS B3/P3 – Processing of Biomass: This baseline and project emission source are

functionally equivalent as there are no changes upstream from point of the waste stream

creation to the processing of the biomass waste between the baseline and the project

condition. The Project impacts on-site biomass waste processing emissions and downstream

waste handling and disposal emissions.

SS B12 - Emissions from Facility Operations: The emissions from diesel usage during

shunting of the biomass to the hauling area are assumed to be functionally equivalent to the

project condition, as the designated SRM waste would require shunting from its production

origin to the FBB Loading area.


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SS B16 – Emissions from Displaced Off-site Heat Generation: This source has been

excluded from the project quantification as there is no heat generation imported into or

exported from the Project boundary. It is not applicable to this Project quantification.

SS B13 – Emissions from Displaced On-site Electricity Generation: This source has

been excluded from the project quantification are there is no previous on-site electricity

generation that is being displaced by the project. It is not applicable to this Project

Quantification.

SS P1 – Emissions from Collection, Transfer and Transport of Biomass: Under the

project condition, the collection, transfer and transport of biomass occurs within the site

boundaries. It is assumed to be functionally equivalent to the baseline condition, as the

biomass is still required to be moved from the production area, to the loading dock within the

site. However, as the baseline source B1 includes transportation of the biomass from the site

to the destination landfill, the emissions from that transfer will remain in the quantification.

Quantification variances since first reporting period

During the first two years of operation the project experienced an issue with the low-pressure

steam meter experiencing repeat failures. This issue was identified and resolved in June 2015

with minor communication errors (<5% of total time) between the meter and SCADA system

from June 2015 to December 2015. From May 9, 2013 – December 31, 2015 correct

measurement data was used to create a statistically conservative average steam flowrate

value that can be substituted when meter error exists, by selecting a confidence interval that

introduced minimal variability in the estimated steam flow volume and impact to the GHG

assertion (<5% uncertainty).

The FBB meter tag for low pressure steam, tagname

“AUTO.FBB_LOW_PRESSURE_STEAM_TOTAL.F_CV” continued to experience communication

errors between the PLC and Proficy program throughout the year with the largest occurrence

spanning the time period from May 19, 2015 to July 15, 2015. The error was introduced due

to the upstream failure of the superheater resulting in steam temperatures exceeding the

remote temperature device (RTD) associated with the meter. The RTD would fail and result

in an erroneous conversion of steam flowrate to reflect values higher than the maximum

output of the boiler of 1,560 klbs/day. This error source was identified and resolved in June

2015. The revised methodology is outlined stepwise below:

1. The daily average and standard deviation of steam generation per month both for

weekday and weekend operations was calculated from available metered data. For

months where no metered steam data was recorded, the annualized daily average was

used (MS,DAILYAVG).

2. For days where a meter ERROR is listed, the conservative value applied is the minimum

steam flowrate value at which a selected percentage of data is equal to or greater

than. This is determined through statistical analysis of a normal data distribution of

metered data (removed of errors) by calculating the mean mass steam flowrate per

day subtract the standard deviation of the steam meter values for the selected

confidence interval (i.e. at a 95% confidence interval, the mean steam flowrate is

subtracted by 1.645 times the standard deviation to achieve a minimum value of which

95% of the data is above). As the weekend flowrates are much smaller and have less

data variability this analysis often resulted in a negative value. When this occurred

steam generation was assumed 0.


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3. Consecutive days with repeat values or meter error occurrences exceeding ,1560

klbs/day output were compared to the operating days assigned to the thermal FBB

operation via the SRM receiving records (tFBB,T).

a. If there was no record of material received for that day the FBB was assumed

non-operational, and the flowrate value set to 0;

b. If there was a record of material received for the day the meter error

occurred, the 95% steam flowrate value was used.

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 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.

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 reconciling the trailer

capacity, the measured mass of biomass, trip distance and fuel efficiency.

Following the implementation of the Carbon Levy in Alberta, the Quantification Protocol for

Energy Generation for the Combustion of Biogas Waste was updated to Version 2.2 in June

2018. This update excludes emission offsets from being generated from levied fossil fuels.

This updated effected sources and sinks B18, P12, and P15 in this project, and caused a net

reduction in the number of eligible offsets.

Lastly 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.

Table 4: Appended Data Parameters to the Monitoring Plan

Source/sink identifier or name: B15

Data parameter: Mass of Ash

Estimation, modeling, measurement or calculation approaches:

Metering

Data unit: Tonnes

Source/origin: Invoices from 3rd Party Haulers: EcoAg Initiatives Inc. and BFI Invoices

Monitoring frequency: Per load


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Description and justification of monitoring method:

Records are provided in the form of scanned invoices direct from the hauler per load of ash accepted. As each load is weighed before removal, this is the highest frequency of data available.

Provide the details for any deviations for the protocol including the justification and rationale:

n/a

Quantification of Source and Sinks

The general methods of quantification for the required greenhouse gas calculations are as

follows:

• Mass of biomass (kg)–The mass of biomass combusted in the FBB consists of SRMs

diverted from landfill and waste materials previously composted. The Proponent

produces weigh tickets for the biomass utilized in the FBB.

• Electricity produced at site (kWh)–Total electricity produced by the generator and

consumed by the FBB building for ancillary equipment is tracked.

• Volume of natural gas (e3m3) displaced –Total energy content of the process

steam produced from the combustion of biomass in the FBB will be used to back-

calculate the total volume of natural gas displaced. The higher heating value of natural

gas will be obtained from the natural gas service-provider(s) (currently ATCO) for the

Plant; the temperature and pressure adjusted energy flow rate of steam produced is

monitored by the Plant’s HMI system.

• Natural Gas used to Start-up FBB (kSCF) – This metric represents the natural gas

consumed by the combustor under-bed burner to begin biomass combustion. This

volume is included in the total natural gas combustion for the FBB plant, meter TAG

ID AUTO.FBB_MAIN_NATURAL_GAS_OLD_TOTAL.F_CV, and is used to calculate

emissions due to plant operation and fuel extraction and processing.

• Natural Gas used to Supplement Biomass Combustion (kSCF) – This metric

represents the natural gas consumed by the combustor over-bed burner to provide

additional heat energy for biomass combustion. This volume is included in the total

natural gas combustion for the FBB plant, meter TAG ID

AUTO.FBB_MAIN_NATURAL_GAS_OLD_TOTAL.F_CV, and is used to calculate

emissions due to plant operation and fuel extraction and processing.


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Table 5: Emission factors used for the Project. provides the emission factors used in the quantification of emissions for this

project. Sample project calculations are included in Section 4.0.

Table 5: Emission factors used for the Project.

Parameter Relevant SS CO2 Emission Factor

CO2e Emission Factor

CH4 Emission Factor

N2O Emission Factor

Source

Natural Gas Combustion

B12, P6, P9, P10, P11, P13, P14, P16

1.918 tonne/e3m3

- 0.000037 tonne/e3m3

0.000033 tonne/e3m3

(Alberta Environment and Sustainable Resource Development, March 2015)

Natural Gas Extraction

B13, P22 0.0427 tonne/e3m3

- 0.00234 tonne/e3m3

0.000004 tonne/e3m3


Natural Gas Processing

B13, P22 0.0904 tonne/e3m3

- 0.000029 tonne/e3m3

0.0000032 tonne/e3m3


Electricity Production

B11 - 0.64 tonnes/MWh

- - (Alberta Environment and Sustainable Resource Development, March 2015)

Electricity Consumption

B11, P6, P9, P10, P11, P13, P14, P16

- 0.59 tonnes/MWh

- - (Alberta Environment and Sustainable Resource Development, March 2015)

Biomass Combustion2

P12 - - 0.3 tonne/TJ 0.004 tonne/TJ IPCC (2006)

Biogenic CO2 B20, P20 - 0.84 t CO2e/tonne fuel

- - National Inventory, 2016 (1990-2014), Table A6-32, wood fuel/ wood

waste

2CO2 emissions from the combustion of bovine by-products are and, therefore, excluded.


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3.2 Baseline and Project Condition

Baseline Condition

The baseline condition for projects applying the Protocol is based on the direct or indirect reduction

of GHG emissions from offsetting fossil fuels used in the application of heat, power, and/or electricity

generation with the combustion of biomass that otherwise would have been sent to a landfill where

anaerobic decomposition would have taken place. For the purposes of this Project, the biomass is

sourced from compostable waste produced by the Plant including bovine by-products, DAF fines,

dewatered activated sludge, tri-canter solids and SRMs that were previously disposed and sent to a

licensed landfill. Prior to the Project, all process steam requirements at the Plant were provided by

natural gas and electricity was solely purchased from the commercial grid.

Project Condition

The FBB reduces the Plant’s waste by utilizing both compostable wastes and SRMs as fuel to displace

a portion of the electricity load and process steam requirements through on-site generation.

3.3 Quantification Plan

The following is a detailed description of the equations used for the identified SS’s in the quantification

of emissions due to CO2, CH4, and N2O for the Project. Reference sources for the emission factors

used in the following equations are listed in Table 2. These calculations will be updated to reflect the

latest Protocol publication.

Net Emissions Reductions

Emission Reduction = Emissions Baseline – Emissions Project

Emissions Baseline = Sum of included 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 Project = Sum of included emissions under the project condition.

=Emissions from Combustion of Biomass and Fossil Fuels (P15) + Emissions from Facility Operation (P12) + Emission from Fuel Extraction and Processing (P4)

(i) Emissions Collection, Transfer, and Transport = emissions under SS B1

𝑆𝑆𝐵1 = 𝐹𝑜𝑠𝑠𝑖𝑙 𝐹𝑢𝑒𝑙 𝑓𝑜𝑟 𝑇𝑟𝑎𝑛𝑠𝑝𝑜𝑟𝑡 × 𝐸𝐹𝑡𝑟𝑎𝑛𝑠𝑝𝑜𝑟𝑡 × 10−6 (1)

Where,


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𝐹𝑜𝑠𝑠𝑖𝑙 𝐹𝑢𝑒𝑙 𝑓𝑜𝑟 𝑇𝑟𝑎𝑛𝑠𝑝𝑜𝑟𝑡 =𝑀𝐵𝑖𝑜𝑚𝑎𝑠𝑠

𝑇𝑟𝑢𝑐𝑘 𝐶𝑎𝑝𝑎𝑐𝑖𝑡𝑦× 𝑇𝑟𝑎𝑛𝑠𝑝𝑜𝑟𝑡 𝐷𝑖𝑠𝑡𝑎𝑛𝑐𝑒 ×

𝑇𝑟𝑢𝑐𝑘 𝐹𝑢𝑒𝑙 𝐸𝑓𝑓𝑖𝑐𝑖𝑒𝑛𝑐𝑦 (2)

And:

EFtransport = Product Transport Emission Factors, g CO2e/l

Truck fuel Efficiency = 39.5 l/100 km (NRCAN, 2013)3

Transport Distance = 750 km round trip

(ii) Emissions BIOMASS, DECOMP = emissions under SS B15 Biomass Disposal

𝑄CH4,𝑡 = ∑ [k × M𝑆𝑅𝑀 × 𝐿𝑜 × 𝑒−𝑘(𝑡−1) × (1 − 𝑅)]𝑡=40𝑡=1 × (1 − 𝑂𝑥) (3)

Where,

QCH4 = mass of methane emitted over 40 years, kg CH4/tonne

k = landfill decay rate, yr-1 MSRM = mass of biomass fed into the FBB, tonnes Lo = Methane Generation Potential, kg CH4/tonne waste t = number of years into the future R = Recovered CH4 at Disposal Site OX = Oxidation Factor And:

𝐿𝑜 = 𝑀𝐶𝐹 × 𝐷𝑂𝐶 × 𝐷𝑂𝐶𝐹 × 𝐹 ×16

12× 1000

𝑘𝑔 𝐶𝐻4

𝑡𝑜𝑛𝑛𝑒 𝑤𝑎𝑠𝑡𝑒 (4)

Where, MCF = Methane Correction Factor DOC = Degradable Organic Carbon DOCF = Fraction of Degradable Organic Carbon Dissimilated F = Fraction of CH4 in Off Gas from Disposal Site And: 𝑘 = 0.00003 × 𝑃𝐶𝑃𝑁 + 0.01 (5) Where, PCPN = annual average precipitation at the nearest weather station, Brownfield AGCM (Atmospheric General Circulation Monitor), Alberta for the most recent 30-yr climate normal period, mm/yr

(iii) Emissions Electricity= emissions under SS B6 Off-site Electricity Generation displaced

in Project

3 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.


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Emissions of CO2e = max(𝐸𝑔𝑒𝑛𝑒𝑟𝑎𝑡𝑒𝑑,𝑝𝑟𝑜𝑗𝑒𝑐𝑡 − 𝐸𝑐𝑜𝑛𝑠𝑢𝑚𝑒𝑑,𝑝𝑟𝑜𝑗𝑒𝑐𝑡 − 𝐸𝑔𝑒𝑛𝑒𝑟𝑎𝑡𝑒𝑑,ℎ𝑖𝑠𝑡𝑜𝑟𝑖𝑐,𝑎𝑑𝑗𝑢𝑠𝑡𝑒𝑑 , 0) × EFP

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.

EFP (tonnes CO2e/kWh) =Emission factor for grid electricity production

(iv) Emissions Thermal Heat = emissions under SS B18 On-site Heat Generation Displaced

by Project

𝐼𝑓 (𝐻𝑔,𝑝𝑟𝑜𝑗 − 𝐻𝑐,𝑝𝑟𝑜𝑗) < 0, 𝑡ℎ𝑒𝑛:

𝐻𝑔,𝑝𝑟𝑜𝑗 = 𝑉𝑁𝐺,𝑒𝑞 × EFNG,𝑖 (7)

Where,

Hg,proj (HLP) = heat generated by the project, GJ Hc,proj (HHP – HLP) = Thermal heat energy used by the project, internal heat loss in the system, GJ 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

And:

𝑉𝑁𝐺,𝑒𝑞 = QLP

HHVNG×1000÷ EfficiencyNG−Boiler (8)

Where,

QLP = Energy of Low Pressure steam produced, GJ HHVNG = higher heating value of natural gas, MJ/m4 EfficiencyNG-Boiler = Boiler HHV efficiency curve of pre-existing natural gas boiler, 80%

Where,

𝑄𝐿𝑃 = 𝐻𝐿𝑃 × 𝑀𝑆 (9)

And: HLP = Enthalpy of low pressure steam, 1195.19 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, then the heat generated by the project must be compared to the average

adjusted historic heat generation over a 3- year period scaled to account for number of head of cattle

4 HHV was used as the boiler efficiency of Saskatoon boiler was calculated using HHV values


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processed. The minimum of these two values will be used to determine the equivalent volume of

natural gas input into equation (8).

(v) Emissions Fuel Extraction/Processing = emissions under SS B4 Fuel Extraction and Processing

ENGXP = ∑ VNGeq × EFNXP𝑖 (10)

Where,

EFNXPi= Emission factor for natural gas extraction and processing, i= CO2, CH4, and N2O,

tonnes/e3m3,Table 5

(vi) Emissions Biogenic CO2 = emissions under SS B20 Biogenic CO2

𝐸𝐵𝐺𝐶𝑂2 = ∑(𝑀𝐵𝐹𝑖 ∗ 𝐸𝐹𝑖,𝐶𝑂2)

𝑖

Where,

EBGCO2 = Biogenic Emissions from the Combustion of Biomass, CO2e

MBFi = Mass of Biofuel Combusted, Tonnes

EFi, CO2 = CO2 Emissions Factor for Biomass Fuel, tCO2/tonne fuel, Table 5: Emission factors

used for the Project.

(vii) Emissions Facility Operation = emissions under SS P12 Facility Operations

Emissions, i = ∑ (𝑉𝑁𝐺 × EFNG,i)𝑖 + (FBBGrid × EFC) (11)

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;

FBBGrid = Electricity required to operate the primary and auxiliary electrical equipment located in the boiler

building, MWh;

EFC = Emission factor for grid electricity consumption, Table 5

(viii) Emissions Combustion of Biomass = emissions under P15 Combustion of Biomass

Biomass Combustion Emissions = ∑ (Energy HP Steam−QNG

𝜂𝐹𝐵𝐵) × EF𝐵,𝑖𝑖 (12)

Where,

EFB, i = CH4 and N2O emission factors for the combustion of biomass, tonne/GJ, Table 5

(ix) Emissions Fuel Extraction/Processing = emissions under SS P4 Fuel Extraction and Processing

Natural Gas Extraction and Processing Emissions = (V𝑁𝐺 × NXPi) (13)

(x) Emissions Biogenic CO2 = emissions under SS P20 Biogenic CO2


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𝐸𝐵𝐺𝐶𝑂2 = ∑(𝑀𝐵𝐹𝑖 ∗ 𝐸𝐹𝑖,𝐶𝑂2)

𝑖

Where,

• EBGCO2 = Biogenic Emissions from the Combustion of Biomass, CO2e

MBFi = Mass of Biofuel Combusted, Tonnes

EFi, CO2 = CO2 Emissions Factor for Biomass Fuel, Table 5: Emission factors used for the

Project.

Offset Eligible Reductions

Eligible Emission Reduction = Emissions Baseline Non-Levied– Emissions Project Non-Levied


= Emissions from Biomass Disposal (B15) + Emission from Fuel Extraction and Processing (B4)



= Emissions from Combustion of Biomass and Fossil Fuels (P15) + Emissions from Facility Operation (P12) + Emission from Fuel Extraction and Processing (P4)

Levied Emissions Reductions

Emission Reduction = Emissions Baseline – Emissions Project


= Emission from Displaced On-site Heat Generation (B18)



= Emissions from Combustion of Biomass and Fossil Fuels (P15) + Emissions from Facility Operation (P12)

3.4 Monitoring Plan

Table 6: Sample Monitoring Plan below outlines details of the key parameters that will be

monitored and how data will be collected for the Project.

Table 6: Sample Monitoring Plan


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Parameter

Source/sink identifier and name

B1, B15, P15 B6, P12 B4, B18 P15 B6, P12

Data parameter Biomass Weight Electricity Production

Steam Mass Produced

Natural Gas Consumption


Estimation, modeling, measurement or calculation approaches

Measurement Direct Metering Measurement via Steam Totalizer

Measurement via Natural Gas flowmeter

Reconciliation of Inline Power Meters MDP 5B and MDB 5B2

Data unit lbs KWh klbs kSCFH kWh

Sources/Origin Truck load scale

weigh tickets

per load

Schneider

Power Logic

ION Inline

Power Meter ID:

MDP 5B2

Proficy Historian

Tagname:

AUTO.FBB_LOW

_PRESSURE_ST

EAM_TOTAL.F_

CV

Proficy Historian

Tagname:

AUTO.FBB_NG_

FLOWRATE.F_C

V

Schneider Power Logic ION Inline

Power Meter ID: MDP 5B

Location of Sampling Points

On site On site On site On site On site

Monitoring frequency

Per load Every 15

minutes

Continuous –

Totalized flow

Continuous –

instantaneous

Flow

Every 15 minutes

Description and justification of monitoring method

Weigh tickets

are used to

measure each

load of waste

entering the

FBB and

provides the

most accurate

method of

determining

parameter.

Represents

highest level of

frequency

possible

Represents

highest level of

frequency

possible

Represents

highest level of

frequency

possible

Power Meter MDB 5B

represents a floating total of

electricity generated and consumed at the FBB plant. By netting out the electricity

generation from each days

reading, the total electricity consumed can be determined.

Uncertainty Biomass scale

calibrated to a

minimum of

120,000 lbs by

20 lb

increments and

ash scale

+/- 0.10% +/- 0.80% +/- 0.14% +/- 0.10%


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calibrated to a

minimum of

120,000 lbs by

20 lb

increments

3.5 Data Management System

Data Management and QA/QC at Cargill Meat Solutions

In general, the data control processes employed for this Project consist of manual and electronic

data capture and reporting, obtaining reference values where applicable, and manual entry of

monthly totals or average values into a Quantification Calculator developed by Bluesource. For

monitoring and quality assurance purposes, the quantification methods and formulas used in the

Quantification Calculator have been reviewed on behalf of the Project Proponent.

There are 3 data streams involved in this Project:

• Electronic data captured (e.g. flow meters);

• Manual data collection reported in third party laboratory analysis reports; and

• Reference values (e.g. Manufacturer’s specifications).

The electronic data capture uses either GE Intelligent Platforms’ Proficy Historian software (for plant

processes), or the PowerLogic ION Monitoring System (for electrical generation/consumption).

Table 7 highlights the internal responsibilities at Cargill with respect to the data management and

handling specifically for this project. The full list can be seen in Appendix E.

Table 7: Cargill Data Management Plan – FBB Offset Project Data Collection

Metric Units Role Frequency of

collection

Frequency of

report

FBB Raw Material

Receiving Records

lbs Maintenance

Clerk

Daily Quarterly

Alberta Processers

Pick up/Hauling

Charge Receipts

Weight /

Invoice / # of

trailers

Accounting One time Quarterly

Mass of LP steam

produced (daily

records)

klbs / Day Environment

al Supervisor

Daily Quarterly

LP Steam

Temperature

10° above

saturation

Temperature

FBB process

Engineer

One time Quarterly

LP Steam Pressure psia FBB Process

Engineer

One time Quarterly


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Metric Units Role Frequency of

collection

Frequency of

report

HP Steam

Temperature

°F FBB Process

Engineer

One time Quarterly

HP Steam Pressure psia FBB Process

Engineer

One time Quarterly

Natural Gas flow SCFH Environment

al Supervisor

Daily Quarterly

Gross Electricity

Generation

MW/Day Maintenance

Clerk

Daily Quarterly

Net Electricity

Generation

MW/Day Maintenance

clerk

Daily Quarterly

Boiler efficiency

curve for pre-

existing natural

gas boiler,

combusting

natural gas to

produce steam.

% FBB Process

Engineer

One time Quarterly

Efficiency of FBB

Boiler

% FBB Process

Engineer

One time Quarterly

Mass of Ash

Collected/Dispose

d

weight / cost Accounting Daily Quarterly

Table 8 summarizes the meter ID for those metrics with electronic data capture, the calibration

schedule and accuracy of the data measurement.

Table 8: Metering maintenance and calibration details

Metric Meter ID Calibration

Schedule

Accuracy Rating

FBB Natural Gas

Consumption

Make/Model: 4” Krohne Vortex

Serial Number: D130000000404817

Meter Tag number: FIT- 9500

To Manufacturer’s

Specification

+/- 0.14%

SRM Weight On-Site DOT Mettler Toledo Weigh

Scale

Inspection every

2 months

Calibrated to a

minimum of


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120,000 lbs by

20 lb increments

Mass of Ash

Collected

On-site DOT Mettler Toledo Weigh

Scale

Inspection every

2 months

Calibrated to a

minimum of

120,000 lbs by

20 lb increments

LP Steam Flow Rosemount 3051 SF DP Flowmeter: Factory

Configured

+/- 0.80%

Electricity

Generation


Power Meter ID: MDP 5B2

To Manufacturer’s

Specification

+/- 0.10%

Electricity

Consumption


Power Meter ID: MDP 5B

To Manufacturer’s

Specification

+/- 0.10%

Data Management and QA/QC at Bluesource

Bluesource holds itself to the highest professional and ethical standards. All staff has experience in

working on GHG projects and/or training in the use of ISO14064-2. Junior staff members are

mentored closely until their level of competence is deemed sufficient for them to work more

independently. This experience and training helps to ensure that errors and omissions are minimised

and that project documentation is compiled in accordance with the principles of relevance,

completeness, consistency, accuracy, transparency and conservativeness.

Figure 8: Quantification Calculator Data Flow illustrates the flow of data from initial collection source,

the variables of interest obtained from each source and the relevant SSs in the calculator. This data

flow is coordinated by Bluesource into the quantification calculator resulting in the final GHG assertion

for the project period.


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Manual Data Collection

GE Intelligent Platforms:Proficy Historian

Industry Literature Reference

QuantificationCalculator GHG Assertion

Raw Material Receiving Records

Biomass Combustion EF

Grid Electricity Consumption/Production Efs

Landfill Design Factors

Natural Gas Combustion, Processing & Extraction EFs

Natural Gas Flowrate

Steam Mass Flowrate

B 9 &10 Decomposition of

Biomass and Methane Collection/

Destruction

P6+ Facility Operation

B9&10 Biomass Decomposition

B11 Electricity Production

P12 Biomass Combustion


Electricity Production

PowerLogic ION Monitoring System

B11 Electricity Production


P22 Fuel Extraction and Processing

P12 Biomass Combustion


P22 Fuel Extraction and Processing

Figure 8: Quantification Calculator Data Flow

Bluesource operates a rigorous internal QA/QC process that is built around the principle of senior

review (i.e. calculations and reports are checked by experienced staff members prior to being

released). The quantification calculator, for example, will be checked for the following:

• Transcription errors/omissions

• Correctly functioning links/formulas in spreadsheets

• Correct and transparent referencing of data sources

• Justification of assumptions

• Use of, and compliance with, most up-to-date versions of protocols, technical guidance, etc.

In addition, the Offset Project Plan and Offset Project Report will also be senior-reviewed for errors,

omissions, clarity, and etcetera.

Issues are recorded in Bluesource’s QA/QC checklist for the Project (and, as necessary, embedded

into the reviewed version of the documents and/or Quantification Calculator) and these will be

corrected before these are sent to the third-party verifier. Staff sign an “Attestation of Quality

Assurance and Quality Control” to document that the QA/QC process was followed. This QA/QC

process is kept under constant review.

Back-up Procedures at Bluesource

Electronic data is backed up by Bluesource’s IT service provider, Calitso.com. A copy of this back-

up procedure is provided as Appendix E – IT Backup Procedure for Bluesource.


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Document Retention Policy at Bluesource

Bluesource operates a documentation retention policy, which all staff must abide by as a condition

of their employment. A copy of this document retention policy is provided as Appendix F – Data

Retention Policy at Bluesource.


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5.0 References

AESRD, 2013.Technical Guidance for Offset Project Developers. [online] Version 4.0, Edmonton,

Alberta: Alberta Environment and Sustainable Resource Development.

Clearstone Engineering Ltd (prepared for CAPP), 2004.Technical Report: A National Inventory of

Greenhouse Gas (GHG), Criteria Air Contaminant (CAC) and Hydrogen Sulphide (H2S) Emissions by

the Upstream Oil and Gas Industry, Volume 1, Overview of the GHG Emissions Inventory. [PDF]

Calgary: Canadian Association of Petroleum Producers.

IPCC 2006, 2006 IPCC Guidelines for National Greenhouse Gas Inventories: Chapter 2, Stationary

Combustion. [online] Prepared by the National Greenhouse Gas Inventories Programme, Eggleston

H.S., Buendia L., Miwa K., Ngara T., and Tanabe K. (eds).Hayama, Japan: Institute for Global

Environmental Strategies.

Alberta Climate Change Office. (June 2018). Energy Generation from the Combustion of Biomass

Waste, version 2.2. Edmonton: Government of Alberta.

Alberta Environment and Sustainable Resource Development. (March 2015). Carbon Offset Emission

Factors Handbook, version 1.0. Edmonton: Government of Alberta .

International Panel on Climate Change. (2006). IPCC Guidelines for National Greenhouse Gas

Inventories, Volume 2, Energy. 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

Government of Alberta. (July 2018). Standard for Greenhouse Gas Emission Offset Project

Developers, version 2.0. Edmonton.

Province of Alberta. (2017). Climate Change and Emissions Management Act Carbon

Competitiveness Incentive Regulation Alberta Regulation 255/2017. Edmonton: Alberta

Queen's Printer.

http://www.nrcan.gc.ca/energy/efficiency/transportation/commercial-vehicles/reports/7607


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Appendix A: Supporting Information


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Parameter File Name(s)

2011 AESRD Approval

(High River Meat

Plant)

AESRD_Approval_No_00000683-03-00

AUC Approval (Power

Plant)

U2011-400

BFI Annual Reports

2010 - 2012

2010 Annual Waste Management Report

AR-00070686-WasteMgmt- 2011-BFI

Class II Landfill -00070686-2012

APC Annual Reports

2010 - 2012

CMB-00010108-2010-Air, Wastewater, Run-off

CMD-00010108-2011 Air, Industrial Wastewater,

Waste Management Part 1 of 2

CMB-00010108-2012 Air, Wastewater, Waste

Management

Letter of Approval for

Historic Crediting

Let_AESRD_fbb_protocol_approval_2013_12_05.pdf


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Appendix B: Cargill Data Management Plan (All Metrics)


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Metric Units Role Frequen

cy of

collectio

n

Frequency

of report

FBB Raw Material

Receiving Records

weight Maintenance Clerk Daily Quarterly

Alberta Processers

Pick up/Hauling

Charge Receipts -

Since January 1,

2010 to Project Start

Date

Weight /

Invoice / # of

trailers

Accounting One time Quarterly

Mass of LP steam

produced (daily

records)

lbs / Day Environmental

Supervisor

Daily Quarterly

LP Steam

Temperature

Temp FBB Process

Engineer

One time Quarterly

LP Steam Pressure PSI FBB Process

Engineer

One time Quarterly

HP Steam

Temperature

Temp FBB Process

Engineer

One time Quarterly

HP Steam Pressure PSI FBB Process

Engineer

One time Quarterly

Natural Gas flow SCFH Environmental

Supervisor

Daily Quarterly

Gross Electricity

Generation

MW/Day Maintenance Clerk Daily Quarterly

Net Electricity

Generation (or

however the

breakdown was

finalized)

MW/Day Maintenance Clerk Daily Quarterly

Boiler efficiency

curve for pre-existing

natural gas boiler,

combusting natural

gas to produce

steam.

n/a FBB Process

Engineer

One time Quarterly


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Efficiency of FBB

Boiler

% FBB Process

Engineer

One time Quarterly

Mass of Ash

Collected/Disposed

weight / cost Accounting Daily Quarterly

Srm - Alberta

Processing /

shunting /

Weight

Accounting Daily Monthly

Tail Switch Pounds Accounting Daily Monthly

Lab Waste Lifts Accounting Daily Monthly

Paunch Weight Accounting Daily Monthly

Tricanter Fines Weight Accounting Daily Monthly

Manure Weight Accounting Daily Monthly

Manure Roseburn

disposal

$ Accounting Daily Monthly

Manure Screener

rental


Paunch and Pen

Manure haul


Wakeford clean up

adhoc

(Piles/blood/hair/Tri

canter)


Sludge weight Weight Accounting Daily Monthly

Sludge Roseburn $ Accounting Daily Monthly

Sludge hauling $ Accounting Daily Monthly

Lbs/hr Steam lbs hr Environmental

Supervisor

Daily Monthly

Hours per day

operation

hours Environmental

Supervisor

Daily Monthly

Production day days Environmental

Supervisor

Daily Monthly


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Nat gas Required GJ/day Environmental

Supervisor

Daily Monthly

MW/Day generated MW/day Environmental

Supervisor

Daily Monthly

Production days days Environmental

Supervisor

Daily Monthly

Electrical consumed

by FBB

KW/day Maintenance Clerk Daily Monthly

R&M Expense

Variable


Production EE labour #ee Maintenance Clerk Daily Monthly

Ash & Bone chip Weight Accounting Daily Monthly

Ammonia cost $ Accounting Daily Monthly

Carbon Credit

payments

$ Accounting Annual Annual

Nat Gas mmbtu Environmental

Supervisor

Daily Monthly

Steam production lbs/day Environmental

Supervisor

Daily Monthly

Steam production lbs / day Environmental

Supervisor

Daily Quarterly

Electricity production MW/Day Environmental

Supervisor

Daily Quarterly

Cost of production $ Environmental

Supervisor

Daily Quarterly

Proof of Calibration Document Environmental

Supervisor

Daily One time


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Appendix C: FBB Plant Load List


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Table 9: Heat Production and Miscellaneous Building Equipment

Location VOLTS Motor

H.P.

Boiler Feedwater Pump #1 EQ#4970 600 150

Boiler Feedwater Pump #2 EQ#4971 600 150

Bed Reinjection Bucket Elevator EQ#4815 600 5

Vibrating Screen Conveyor Motor EQ#4826 600 7.5

Superheater Retractable Sootblower #1 EQ#4931 600 0.6

Superheater Retractable Sootblower #2 EQ#5130 600 0.6

Evaporator Rotary Sootblower #1 EQ#5131 600 1.25






Economizer Rotary Sootblower #1 EQ#5137 600 1.25




FD Fan Motor EQ#5063 4160 350

ID Fan Motor EQ#4846 4160 300

Ash Storage Bin Vent Fan EQ#5114 600 5

Ash Blower EQ#4946 600 30

Penthouse Vent Fan EQ#4836 600 1.5

Baghouse Bridge Crane EQ#4835 600 1.25

Baghouse Screw Conveyor EQ#4837 600 5


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H.P.

Baghouse Module 1 Rotary Feeder EQ#4831 600 1



Ash Conditioner Rotary Feeder EQ#4838 600 2

Ash Conditioner Screw Conveyor EQ#4843 600 10

Limestone Metering Screw EQ#4823 600 0.3

Super Sack Hoist EQ#4818 600 1.5

Aqueous Ammonia Pump #1 EQ#4848 600 1

Aqueous Ammonia Pump #2 EQ#4849 600 1

Condensate Sump Pump EQ#5582 600 3

Air Compressor EQ#4909 600 100

Lighting Equipment Panel 75 KVA 120/208 120 72

Equipment Panel 75 KVA 120/208V 120 43

UPS Panel 45 KVA 120/208V 120 43

347/600V Lighting Panel 225 KVA 600 217

347/600V Equipment Panel 225 KVA 600 217

Make-Up Air Unit (MUA) EQ#4912 600 60

Overhead Door #1 EQ#4920 600 2




Electrical Room MCC HVAC EQ#4913 600 30

Office/Welfare HVAC EQ#4914 600 30

Welding Receptacles 1,2 EQ#'s 5181 & 5182 600 30


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H.P.

Welding Receptacles 3,4 EQ #'s 5183 & 5184 600 30

Exhaust Fan #1 EQ#4917 600 10

Exhaust Fan #2 EQ#4918 600 10

Heat Tracing Line #1 Boiler Feedwater EQ#5185 600 5

Heat Tracing Line #2 Wastewater EQ#5186 600 5

Heat Tracing Line #3 Sewage EQ#5187 600 5

Heat Tracing Line #4 Cold Water EQ#5188 600 5

Heat Tracing Line #5 Re-Use EQ#5189 600 5

Heat Tracing Line #6 Paunch EQ#5190 600 5

Heat Tracing Line #7 Ash Bin Water Line EQ#5191 600 5

Heat Tracing Line #8 Boiler Ash Line EQ#5192 600 5

Heat Tracing Line #9 Economizer Ash Line EQ#5193 600 5

Heat Tracing Line #10 Baghouse Ash Line EQ#5194 600 5

Sewage Pump EQ#4919 600 30

Bridge Crane Raw Material EQ#4747 600 30

Baghouse Hopper Heater EQ#5116 600 20

Turbosteam Oil Cooling Pump EQ#5195 600 5

Turbosteam Oil Cooling Fan EQ#5196 600 5

Total H.P. 2080.75

Table 10: Fuel Production Equipment: SRM System


H.P.

SRM Truck Bin Metering Screw #1 (SRM-001A)

EQ#4731

600 5


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SRM Truck Bin Metering Screw #2 (SRM-001B)

EQ#4732

600 5

SRM Truck Bin Metering Screw #3 (SRM-001C)

EQ#4733

600 5

SRM Truck Bin Metering Screw #4 (SRM-001D)

EQ#4734

600 5

SRM Metering Bin Discharge Screw #1 (SRM-002)

EQ#4735

600 3

SRM Cross Auger to Paunch (SRM-003) EQ#4737 600 3

SRM Metering Bin Discharge Screw #2 (SRM-004)

EQ#4736

600 5

SRM Prebreaker Feed Screw (SRM-005) EQ#4738 600 5

SRM Prebreaker (SRM-007) EQ#4643 600 75

SRM Feed Auger to Lamella Pump (SRM-008)

EQ#4740

600 3

SRM Lamella Pump (SRM-009) EQ#4741 600 10

Total H.P. 124

Table 11: Fuel Production equipment: Paunch System


H.P.

Paunch Truck Bin Metering Screw #1 (PA-001A)

EQ#4749

600 3

Paunch Truck Bin Metering Screw #2 (PA-001B)

EQ#4750

600 3

Paunch Bin Discharge Screw #1 (PA-002) EQ#4751 600 2



Press Feed Buffering Bin Leveling Screw (PA-005A)

EQ#4756

600 5


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Press Feed Buffering Bin Metering Screw #1 (PA-005B)

EQ#4757

600 5

Press Feed Buffering Bin Metering Screw #2 (PA-005C)

EQ#4758

600 5

Press Feed Buffering Bin Metering Screw #3 (PA-005D)

EQ#4759

600 5

Press Feed Buffering Bin Discharge Screw (PA-006)

EQ#4760

600 7.5

Twin Screw Press (PA-009) EQ#4763 600 125

Twin Screw Press Lubrication Pump (PA-010) EQ#4764 600 2

Pressed Paunch Bin Leveling Screw (PA-011A) EQ#4766 600 5

Pressed Paunch Bin Metering Screw #1 (PA-011B)

EQ#4767

600 2

Pressed Paunch Bin Metering Screw #2 (PA-011C)

EQ#4768

600 2

Pressed Paunch Bin Metering Screw #3 (PA-011D)

EQ#4769

600 2

Pressed Paunch Metering Bin Discharge Screw (PA-012)

EQ#4770

600 3

Pressed Paunch Bucket Lift Feed Screw (PA-013)

EQ#4771

600 5

Paunch Bucket Elevator (PA-014) EQ#4772 600 10

Paunch Bucket Lift Discharge Screw (PA-015) EQ#4773 600 5

Pressed Paunch Discharge to Truck Loadout (PA-016)

EQ#4775

600 5

Paunch Fuel Metering Bin (PA-017) EQ#4806 600 7.5

Rotary Screen (PA-018) EQ#2215 600 1

Hydrosieve Pump #1 (PA-019) EQ#4781 600 7.5




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Total

H.P.

246

Table 12: Feedstock Transmission Equipment


H.P.

50 HP PAUNCH PUMPS FED IN BASEMENT #1 600 50

50 HP PAUNCH PUMPS FED IN BASEMENT #2 600 50

Total

H.P.

100


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Appendix D: Approval Letter for Historic Crediting


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Appendix E: IT Backup Procedure for Bluesource

Backup Procedure

Prepared For: Blue Source

Objective

To minimize interruptions to business by insuring that operation can be restored in case of

• Loss of any amount of information due to accidental or malicious deletion;

• Failure of one or more computers or components such as a hard disk drive; or

• A disaster resulting in loss of the entire infrastructure, or loss of access to it.

Backup Procedure

1. Backup Rotation

• Rotation is continues and automatic in accordance with retention specifiedin item 2.

• All off-site data is stored in Canada at a SSAE 16, CSAE 3416 and ISA3402certified data center.

2. Retention

• 30 days of continuous data change, and nightly system state is off site in datacenter. Data is stored both on-site and off-site

• Data can be restored as far as 30 days back from on-site and off-site backups

3. Backup Schedule

• Data backup

� Full backup is scheduled to run nightly at 8:00PM

• Image Backup (Entire server backup) – Disaster Recovery Backup

� Scheduled to run nightly at 3am

Off site storage

• All off-site data is stored in Canada at a SSAE 16, CSAE 3416 andISA3402 certified data center.


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Appendix F: Document Retention Policy at Bluesource

Last Revision: August 2, 2017

Document Retention Policy, version 1.4.

1. All documents relevant to Offset Projects will be kept, in at least

electronic format, and where possible, in hardcopy format, for

a. At least 10 years beyond the last year in which credits are created

(e.g. a project that creates credits between 2010-2018 will have

all records kept until at least 2028), or

b. As required by the Offset Project Program

whichever period is longer.

2. Hard copy documents will be kept in project folders in our Blue Source

Canada head office location, which is currently Suite 1605, 840 – 7th Av

SW, Calgary, AB, T2P 3G2. All electronic documents will be saved to the

appropriate project folder on the Calgary Server (“S:\ drive”).

3. The S:\ drive will be backed up in accordance with Blue Source’s IT

Backup Procedure, which may change from time to time.

4. Blue Source’s preference is to keep all documents in electronic form,

wherever possible.

5. All employees will comply with this policy as a condition of their

employment.

Yvan Champagne

President, Blue Source Canada ULC

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