Verdant Energy Ltd - DAPP Power Electricity Generation ... · Verdant Energy Ltd - DAPP Power Electric Generation Facility October 2018 . Page 5 of 36 Version 2.0 Project Plan Form

Verdant Energy Ltd - DAPP Power Electric Generation Facility

October 2018

Version 2.0 Project Plan Template – July 2018

Offset Project Plan


Project Developer:

Fortistar Biomass

Prepared by:

Cap-Op Energy

Date:

October 4, 2018


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Version 2.0 Project Plan Form – July 2018

Table of Contents

1.0 Contact Information .............................................................................................. 3 2.0 Project Scope and Site Description .......................................................................... 3

2.1 Project Description ................................................................................................ 6 2.2 Protocol ............................................................................................................... 6 2.3 Risks ................................................................................................................... 7

3.0 Project Quantification ............................................................................................ 8 3.1 Inventory or Sources and Sinks .............................................................................. 8 3.2 Baseline and Project Condition ................................................................................ 9 3.3 Quantification Plan .............................................................................................. 10 3.4 Monitoring Plan ................................................................................................... 15 3.5 Data Management System.................................................................................... 27

4.0 Project Developer Signature ................................................................................. 31 5.0 References ......................................................................................................... 32 Appendix A: Supporting Information ..................................................................................... 33

List of Tables

Table 1: Project Contact Information ...................................................................................... 3 Table 2: Project Information .................................................................................................. 3 Figure 1: Dapp Generating Facility Plant Layout ....................................................................... 5 Table 3: List of Sources and Sinks Included in the Project Quantification ..................................... 8 Table 5: Meter Maintenance & Calibration.............................................................................. 28 Figure 2: Diesel Fuel Consumption Data Management ............................................................. 33 Figure 3: Gasoline Consumption Data Management ................................................................ 34 Figure 4: Electricity Production and Consumption Data Management......................................... 34 Figure 5: Natural Gas Consumption Data Management ............................................................ 35 Figure 6: Propane Consumption Data Management ................................................................. 35 Figure 7: Biomass Diversion Data Management ...................................................................... 36


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1.0 Contact Information

Table 1: Project Contact Information

Project Developer Contact Information Additional Contact Information

Dapp Power L.P. Dapp Power L.P.

Grant Noll, Vice President - Operations Dominick Zimmerman, Plant Manager/Chief

Engineer

201 – 525 11th Avenue SW Box 6, Site 4, RR1

Calgary, AB, T2R 0C9 Westlock, AB, T7P 2N9

(403) – 261 - 9754 (780) 954 - 2089

www.fortistar.com www.fortistar.com

[email protected] [email protected]

Authorized Project Contact (if applicable)

Cap-Op Energy

Cooper Robinson, Managing Director

610 – 600 6 Ave SW

Calgary, AB, T2P 0S5

(403) 457 - 1029

www.capopenergy.com

[email protected]

2.0 Project Scope and Site Description

Table 2: Project Information

Project title Verdant Energy Ltd – Dapp Power Electric Generation Facility

Project purpose and

objectives

Dapp Power LP and its wholly owned subsidiary Biofuels Inc. (the Project)

is an electrical energy from biomass project located northwest of

Westlock, Alberta and wood recycling depot located at a landfill on the

mailto:[email protected]




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west side of Edmonton. The purpose of the project is to generate carbon

offsets from:

• Indirect GHG emission reductions by using biomass to offset non-

renewable electricity production; and

• Creating direct GHG emission reductions by avoiding methane

emissions from the decomposition of biomass in landfills.

Emission reductions from this project are generated under the

Quantification Protocol for Energy Generation from the Combustion of

Biomass Waste, Version 2.2, June 2018 and therefore meet the

requirements of the Alberta Offset System.

Activity start date September 2005

Offset crediting

period

January 1, 2006 to December 31, 2013; with a five-year extension from

January 1, 2014 to December 31, 2018

Estimated emission

reductions/

sequestration

100,000 to 150,000 tonnes CO2e/year.

Over the thirteen years of the project thus far, approximately 2.5 M

tonnes of CO2e have been be reduced.

Unique site identifier Dapp Generation Facility is located north of the town of Westlock, AB. The

legal description of the site is SW1/4 Section 1, Township 63, Range 2,

W5. The corresponding latitude and longitude is:

54.415042, -114.176788

The wood recycling depot is located on the Northland Sand and Gravel

Landfill in Edmonton at 231st St and Highway 16A in Parkland County.

The corresponding latitude and longitude is:

53.546444, -113.718401

Is the project located

in Alberta?

Yes

Project boundary The project boundary includes energy generation at the Dapp generating

facility and the waste biomass processing facility owned by Bio-Fuels Inc.

The specific physical boundaries are the facility boundaries located at the

areas identified above. A map of the Dapp generating facility plant layout

is included in Figure 1.

Waste wood biomass is received at Biofuels’ site and processed before

being shipped to the Dapp Generating Facility. Biofuels Inc. also sources

processed wood waste from other landfills or waste transfer stations,

which is transported directly to Dapp Power. This reduces handling and

transportation costs for the waste owner.

Ownership The Project is registered and operated under the name of Dapp Power

Limited Partnership (LP). It is owned and operated by Verdant Energy

Ltd, an Alberta based enterprise under the FORTISTAR Biomass Group of


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White Plans, New York. Only Dapp and it’s holding companies have

entitlement to the benefits associated with the emission offsets, and the

right to sell the credits.

Figure 1: Dapp Generating Facility Plant Layout


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2.1 Project Description

The project generates carbon-offset credits in two ways:

1. Using biomass to offset non-renewable electricity production (indirect GHG reductions);

and,

2. Diverting biomass waste away from landfills (direct GHG emission reductions).

If Verdant Energy did not initiate this electrical generation project, the waste biomass would

have been sent to landfill and decomposed anaerobically to form methane emissions. Other

biomass would be sent to beehive or olivine burners where combustion emissions were emitted

with no heat or electricity recovered, stockpiled, or disposed of by other unknown or

undocumented means. For the purposes of the flexibility mechanism applied, only feedstock with

documented disposal for landfill will generated avoided landfill emission credits. There was no

baseline activity at the Dapp Generating Facility prior to the project start date.

Biomass arrives at Dapp in one of two ways:

• Direct transportation to Dapp Generating Facility; or,

• Transportation to Bio-Fuels Inc. wood recycling depot, where it is processed and then

transported approximately 135 km to the Generating Facility

Biomass that is directly transported is weighed at the Ancoma truck scale and then received at

its wood receiving system. Wood waste is processed to proper size through a ‘hog’ located at the

plant site. A front loader moves the biomass either into open-air storage or to a fuel reclaim

system that carries it by conveyor to the power plant. Once in the plant, biomass is fed into a

steam power boiler that generated steam to turn a steam turbine coupled to an electric

generator. Steam exhaust is cooled and returned to the boiler in a closed loop system.

Biomass received by Bio-Fuels Inc includes construction and demolition waste, shipping pallets

and crates, other industrial/commercial wood waste and tree trimmings. Biomass is processed

through a 500 hp diesel powered wood shredder, with the ability to separate nails and metals.

Mobile equipment is used to load tractor-trailer units with the processed waste, which is shipped

to the Dapp Generating Station using Dapp owned and 3rd-Party owned trucks.

All collected waste biomass is combusted to generate zero-emission electricity for the Alberta

grid, offsetting high-emission-intensity electricity currently supplied to the grid. The project

produces 16.5 MW of electricity using a bubbling fluidized bed gasifier/boiler and steam turbine.

The expected remaining life of the Generating Facility is 10-15 years, with regular maintenance

and equipment upgrades.

2.2 Protocol

This project uses the Protocol for Energy Generation from the Combustion of Biomass Waste,

Version 2.2, June 2018. This project is directly relevant to the protocol because emissions offsets

are produced from the combustion of waste biomass (waste wood products), and from the

avoided methane emissions from diverting woody biomass destined for landfills. In the absence

of this project, woody biomass would end up in landfills and zero-emission electricity would not

be generated from biomass combustion.

This project meets the general eligibility criteria for offset projects within the Alberta Offset

System as outlined in Section 1.2 of the Carbon Competitiveness Incentive Regulation, as well

as the specific requirements for the Protocol, namely:

• The first batch of feedstock was received in 2005, which is after the specified date of January

1, 2002;


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• Dapp Power and its wholly owned subsidiary Biofuels Inc. are Alberta based;

• The project offset credits were generated from activities that go beyond business and usual

practices, and the changes in practices were not required by law or regulation;

• Any carbon offset credits generated in this project will be serialized for use in the Alberta

Offset System only and will not be used or counted in any other jurisdiction;

• Reductions achieved by the project are based on actual measurement and monitoring as per

the requirements of the protocol; and

• The project meets the offset system eligibility criteria specified in the CCIR, standards and

guidance documents for the Alberta Offset System, and will be verified according to the CCIR.

The flexibility mechanism applied to this project includes diversion of biomass waste from

landfills. The Dapp generating facility has been diverting waste wood from landfills and generating

credits for methane avoidance for the last 13 years, at which point the original records were

provided to the Climate Change Office. (Section 5.1.2). Flexibility quantification methods were

also applied, including site-specific emission factors and default factors in other locations.

Environment Canada or equivalent emission factors were used for fossil fuel emissions and

biomass fuel combustion. Boiler fuel consumption is calculated based on steam production, fuel

density, moisture content and fuel inventory surveys.

The Protocol has been fully approved and registered under the Alberta Offset System. There are

no deviations that apply to this project.

2.3 Risks

The project faces several risks as part of its operations and business environment, including:

• Fuel Supply Shortfall - Wood biomass supply may be interrupted due to market changes

that impact the economic circumstances of suppliers. In order to help mitigate this risk, the

Project obtains wood biomass from numerous suppliers. Currently, annual biomass supply

exceeds project needs.

• Plant Availability – Physical or technical issues may arise at the plant. This may curtail or

cease production and therefore, would have a direct impact on CO2e offsets created. To

mitigate this risk, the plant has 24-hours/day staff presence as well as industry standard

operating and maintenance practices. The plant is also insured for significant property and

equipment loss.

• Infrastructure Failure – Road or electrical grid access could be lost due to events beyond the

Project’s control. This would be an event of force majeure and could curtail or cease

production; directly impacting the volume of offsets created. As stated above, to mitigate this

risk, the plant has 24-hours/day staff presence as well as industry standard operating and

maintenance practices. The plant is also insured for significant property and equipment loss.

Approximately one to two months of fuel supply are stock piled at the facility to mitigate

against this risk. Fuel piles are consumed first-in-first-out (FIFO).

• Commercial or Market Condtions - Plant operations may be curtailed or ceased due to negative

changes in power markets or other commercial circumstances affecting economic viability.

• Legislative or Regulatory Changes - Changes to regulations, protocols or legislation affecting

recognition of environmental attributes of the project may jeopardize the viability of the

project revenue.

The plant operates under approval by the Alberta Energy Utilities Board and Alberta Environment

Sustainable Resource Development. Therefore the plant must meet certain requirements in order

to continue to be in regulatory compliance.


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3.0 Project Quantification

3.1 Inventory or Sources and Sinks

The total list of selected sources and sinks included in this project are included below. Many other

sources and sinks were excluded from the quantification as per guidance from the quantification

protocol.

Table 3: List of Sources and Sinks Included in the Project Quantification

Included

Source or Sink

Justification for

Selection

Tracking

Description

Quantification

Description

B1 & P1:

Collection,

Transfer, and

Transport of

Biomass

Collection and transport

may change in project

condition depending on

type of biomass residues,

and pre-processing

required

Feedstock collection

and transport

documented and any

additional fuels in

project condition

tracked and

measured

Fuel usage directly

metered or measured

and emission factors

applied

B3 & P3:

Processing of

Biomass

Processing variable by

biomass waste type and

conditions, all electricity

or fuel use should be

tracked and applied

Any energy or fuel

used for feedstock

processing

documented, tracked

and measured

Fuel usage and/or

electricity directly

metered or measured


applied

B4 & P4: Fuel

Extraction &

Processing

Baseline emissions are

expected to be higher

than project emissions

Volumes and types of

fuels used tracked

Emission factors for

fuel extraction &

processing applied

B6: Offsite

Electricity

Generation

Displaced

Off-site emissions

displaced through export

of electricity (there was

no heat exported)

Using facility

production data

Directly metered

electricity generation

from facility

operations

B12 & P12:

Facility

Operations

Emissions from electricity

use or other fuels for

facility operations &

equipment

All processes

documented and any

additional fuel or

electricity usage

tracked

Fuel usage and/or

electricity directly

metered or measured


applied

B13: On-site

Electricity

Generation

Displaced in

Project

Emissions that occurred

to generate electricity in

the baseline conditions

which have been

displaced by project

activity (no heat)

Using facility

production data

(projection based)

Directly metered

electricity generation

from facility

operations


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Included

Source or Sink

Justification for

Selection

Tracking

Description

Quantification

Description

P15: Combustion

of Biomass or

Fossil Fuels

Emissions (CH4 and N2O)

resulting from the

combustion of biomass

must be quantified,

biogenic CO2 emissions

are excluded

Using facility

production data on

biogenic biomass

processed and

consumed

Biomass measured

based on change in

fuel inventory (by

survey) and scale

records of fuel

receipts. Fossil fuel

consumption is

directly measured by

meter.

B15: Disposal of

Biomass

Disposal of biomass

varies according to type

and source – this was

quantified because the

flexibility mechanism was

applied

Using biogenic

biomass

transportation &

feedstock records

Biomass measured

based on change in

fuel inventory (by

survey) and scale

records of fuel

receipts.

3.2 Baseline and Project Condition

The baseline condition is characterized by the following:

• The production of energy from fossil fuels for electricity; and,

• The disposal of biomass by a means described by a flexibility mechanism in Section 1.3 of

the protocol.

Baseline electricity emissions are quantified using published grid emission factors, while baseline

upstream diversion emissions are quantified based on historical data of biomass waste disposal.

The waste streams include the following suppliers:

Landfill Wood –construction, demolition and commercial/industrial wood waste diverted

from the following landfills or related transfer stations:

o Northland Sand and Gravel Landfill (Biofuels Inc operating site);

o Edmonton Waste Management Centre/Ryley Landfill.

None of the landfills sites listed above currently have landfill gas capture systems in place for

incoming waste streams or active cells. The Edmonton Waste Management Center diverts wood

waste for compost as a first priority and any material sent to Dapp is excess material or unsuitable

for their compost needs.

Forest Products Mill Residuals (previously incinerated)

o Slave Lake Pulp (SLP) – forest trimmings and mill by-product not diverted from

landfill;

o Alberta Plywood Ltd (APL) – forest trimmings and mill by-product not landfill

diverted.

o Blue Ridge Lumber


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o Other surrounding mills on a periodic basis including Vanderwell Contractors, Millar

Western Forest Products, Tolko Industries

The project condition is characterized by the following:

• Transportation and Processing of waste biomass directly received by Dapp Generating Facility;

• Transportation and Processing waste biomass received by Bio Fuels Inc. (diverted from

landfills);

• Transportation of diverted waste biomass from Bio Fuels Inc. to Dapp Generating Facility;

• Electricity generation at Dapp facility from combustion of waste biomass

The project is estimated to result in 150,000 – 225,000 tCO2e that would be avoided from the

atmosphere yearly. These emission reductions are attributed to both the processing of biomass

to generate electricity and methane avoidance from landfill diversion of the eligible wood waste

materials.

The baseline and project conditions are functionally equivalent because electricity produced in

the project condition displaces electricity generated in the baseline scenario, and wood waste

combusted in the project scenario replaces alternative disposal methods employed in the

baseline scenario.

3.3 Quantification Plan

The quantification of the reductions, removals and reversals of relevant SS’s for each of the

greenhouse gases will be completed using the methodologies outlined in Section 4.1.2 and 4.1.3

of the Protocol. The methodologies serve to complete the following equations for calculating

emission reductions:

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

Emissions Non-Levied Baseline = (B4) Emissions Fuel Extraction and Processing + (B6) Emissions Off-Site

Electricity + (B13) Emissions On-site Electricity + (B15) Emissions Disposal of

Biomass + (B12) Emissions Facility Operation + (B3) Emissions Processing of

Biomass

Emissions Non-Levied Project = (P4) Emissions Fuel Extraction and Processing + (P15) Emissions Combustion

of Biomass + (P12) Emissions Facility Operations + (P3) Emissions Processing

of Biomass

Levied Emission Reductions = Emissions Levied Baseline – Emissions Levied Project

Emissions Levied Baseline = (B1) Emissions Collection, Transfer, Transport + (B3) Emissions Processing of

Biomass + (B12) Emissions Facility Operations + (B16) Emissions Off-Site Heat

+ (B18) Emissions On-Site Heat

Emissions Levied Project = (P1) Emissions Collection, Transfer, Transport + (P3) Emissions Biomass

Processing + (P12) Emissions Facility Operations + (P15) Emissions Combustion

of Biomass & Fossil Fuels

Where:

Emissions Baseline = Sum of included emissions under the baseline condition

Emissions Collection, Transfer, Transport = Emissions under SS B1 Collection, Transfer and Transport of

Biomass


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Emissions Biomass Processing = Emissions under SS B3 Processing of Biomass

Emissions Fuel Extraction / Processing = Emissions under SS B4 Fuel Extraction / Processing

Emissions Electricity = Emissions under SS B6 Offsite Electricity Generation

Displaced in Project and SS B13 Onsite Electricity Generation –

(there is no applicable heat generation that is relevant to this

project)

Emissions Facility Operations = Emissions under SS B12 Facility Operations

Emissions Biomass Disposal = Emissions under SS B15 Disposal of Biomass

Emissions Project = Sum of included emissions under the project condition

Emissions Collection, Transfer, Transport = Emissions under SS P1 Collection, Transfer and Transport of

Biomass

Emissions Biomass Processing = Emissions under SS P3 Processing of Biomass

Emissions Fuel Extraction / Processing = Emissions under SS P4 Fuel Extraction / Processing

Emissions Facility Operations = Emissions under SS P12 Facility Operations

Emissions Combustion of Biomass = Emissions under SS P15 Combustion of Biomass and Fossil

Fuels

As per the protocol, emissions from levied fuels are quantified and reported where there is a

difference in the project and baseline emissions. The following list includes the parameters that will

be measured and those that will be estimated:

Source or

Sink

Procedure Description Justification

B1 & P1 Measured Volume of fuel used for

biomass collection & transport

Direct measurement of combusted

fuel – highest frequency possible

B1 & P1 Estimated Emission factors for fuel

combustion

Reference values adjusted as

needed by ECCC

B3 & P3 Measured Volume of fuel used for

biomass processing



B3 & P3 Measured Volume of electricity consumed

for biomass processing

Direct measurement of electricity –

or vendor invoice


combustion & electricity


needed by ECCC or ACCO

B4 & P4 Measured Volume of fuel for extraction

and processing emissions




extraction and processing



B12 & P12 Measured Volume of fuel used for facility

operations



B12 & P12 Measured Volume of electricity consumed

for facility operations

Direct measurement of electricity –

or vendor invoice


combustion & electricity



B13 N/A Emissions from electricity

generation displaced on-site

Not applicable since there is no on-

site electricity generation displaced

B6 Measured Electricity generated by the

project

Continuous direct metering

represents industry practice and

the highest level of detail


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B6 N/A Electricity consumed by the

project

There is no additional electricity

consumed by the project, electricity

is net generation sold to grid

B6 N/A Historic levels of on-site

generation

There is no historic displacement of

electricity in the project, electricity

is net generation sold to grid

B6 Estimated Emission factor for grid

electricity


needed by ACCO

P15 Measured Mass of biomass fuel

combusted

Direct measurement of biomass

received by the facility according to

industry practice

P15 Estimated CH4 and N2O emission factors

for waste wood combustion


needed

P15 N/A Volume of supplementary fossil

fuel combusted

No supplementary fossil fuel was

combusted in the project

B15 (flex-

1)

Measured Biomass waste diverted from

landfill or stockpile

Measurement is more accurate than

estimation – scale used for each

truckload diverted from landfill

B15 (flex-

1)

Calculated Amount of methane emitted

from stockpile or landfill

Using methodology and factors

published by ACCO

B15 (flex-

2)

Measured Biomass waste diverted from

open air combustion


estimation – scale

B15 (flex-

2)

Estimated CH4 and N2O emission factors

for open air combustion

Using AP-42 emission factors

(section 13.1)

B20 & P20 Measured Mass of Biomass Fuel

Combusted


estimation – scale used for each

truckload diverted from landfill

B20 & P20 Estimated CO2 emission factors for waste

wood combustion

Reference values are adjusted as

needed (NIR)

The records and project information used to support the specified gas emission reduction or

sequestration quantification is included in the Monitoring Plan below. Baseline documentation

includes:

• Electronic recording of values of logged primary parameters for each measurement

interval,

• Written logs of operations and maintenance of the project system including notion of all

shutdowns, start-ups and process adjustment,

• Proof of ownership or right to transact emission offsets generated,

• Records to show any fossil fuel or electricity use in the baseline,

• Retention of all copies of logs and all logged data for a period of seven years, and

• Retention of all records available for review by verification body.

Project documentation includes:

• Direct evidence of electricity production from biomass,

• Information for other fuels used including type, quantity and activity for fuel use,

• Records of biomass retention and storage on-site, and

• Historic production of biomass for three years immediately prior to project implementation.


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The records to support the flexibility mechanisms, whereby the baseline is organic woody biomass

going to landfill or open-air combusted include:

• Records for a period of at least three years prior to implementation of the project activity

that show that the waste stream was being disposed at a waste management facility with

an EPEA registration or approval,

• Records showing how the waste was treated/disposed at the waste management facility,

• Records showing a historical practice for disposing of biomass and the estimated volumes

of biomass combusted in open-air, and

• Proof that harvest levels or forest utilization standards are not generating more biomass

feedstock than occurred in the baseline condition as a result of diverting biomass from

open-air combustion.

Below is an example of the quantification approach used in this project. The tables below specify

the types of input-data and emissions factors used.

Input Description Input Value (for period)

Electricity Generation 73,545,091 KWH

Electricity Purchased 659,792 KWH

Dapp Wood Consumed 128,465 Tonnes

Total Landfill Diversion 27,604 Tonnes

Dapp Natural Gas 7,764 GJ

Total Gasoline Usage 19,031 L

Total Propane 643 L

Total Site Diesel 235,274 L

Dapp Truck Diesel 145,516 L

3rd Party Transport Diesel 552,660 L

3rd Party Supplier Diesel 24,182 L

Emission Factors Used

GWP CH4 25

GWP N2O 298

Emission Factor Electricity Generation 0.59 tCO2e/MWH

Emission Factor Electricity Consumption 0.64 tCO2e/MWH

Emission Factor Diesel 2.66E-3 tCO2/L

Emission Factor Diesel 1.4E-7 tCH4/L

Emission Factor Diesel 8.2E-8 tN2O/L

Emission Factor Gasoline 2.29E-3 tCO2/L

Emission Factor Gasoline 1.4E-7 tCH4/L

Emission Factor Gasoline 2.2E-8 tN2O/L

Emission Factor Natural Gas 1.92E-3 tCO2/m3

Emission Factor Natural Gas 4.9E-7 tCH4/m3

Emission Factor Natural Gas 4.9E-8 TN2O/m3

Emission Factor Propane 1.51E-3 tCO2/L

Emission Factor Propane 2.4E-8 tCH4/L

Emission Factor Propane 1.08E-7 tN2O/L

Emission Factor Diesel Extraction 1.38E-4 tCO2/L

Emission Factor Diesel Extraction 1.09E-5 tCH4/L

Emission Factor Diesel Extraction 4E-9 tN2O/L

Emission Factor Natural Gas 1.33E-4 tCO2/m3

Emission Factor Natural Gas 2.6E-6 tCH4/m3


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Input Description Input Value (for period)

Emission Factor Natural Gas 7E-9 tN2O/m3

Emission Factor Gasoline 1.38E-4 tCO2/L

Emission Factor Gasoline 1.09E-5 tCH4/L

Emission Factor Gasoline 4E-9 tN2O/L

Emission Factor Open Air Combustion 5.53E-3 tCH4/t

Emission Factor Open Air Combustion 2.08E-4 tN2O/t

Emission Factor Biomass 0.84 tCO2/t

Emission Factor Biomass 9E-5 tCH4/t

Emission Factor Biomass 6E-5 tN2O/t

The table below presents a summary view of the emission reduction quantification that is completed

using a purpose-built Excel™ spreadsheet. The quantification distinguishes between levied and non-

levied emissions. Note that baseline counterparts to some of the project SS’s listed below are

excluded from the table for brevity since they would be null values. Specifically, B1, B3, B4, B12,

B13, B16, and B18 are not relevant to the project quantification.

Non-Levied Baseline Emissions tCO2 tCH4 tN2O tCO2e Total CO2e

B6 - Offsite Electricity Generation Displaced in Project 43,391.6 43,391.6

B15 - Disposal of Biomass (Flex 1 and 2) 1,260.4 31,509.5

B15 - Disposal of Biomass (Flex 3) 0.0 0.0 0.0

B15 - Disposal of Biomass (Flex 4) 0.0 0.0 0.0

Total Non-Levied Baseline Emissions 0.0 1,260.4 0.0 43,391.6 74,901.1

Non-Levied Project Emissions tCO2 tCH4 tN2O tCO2e Total CO2e

P3 - Processing of Biomass (Electricity) 18.6 18.6

P4 - Extraction and Processing of Fuels (nat gas, diesel, gasoline)

46.3 2.0 0.0 97.7

P15 - Combustion of Biomass and Fossil Fuels 11.6 7.7 2,586.0

P12 - Facility Operations (Electricity) 403.6 403.6

Total Non-Levied Project Emissions 46.3 13.6 7.7 422.2 3,105.9

Total Eligible Emission Reductions 0.0 1,246.8 -7.7 42,969.4 71,795.1

Levied Baseline Emissions tCO2 tCH4 tN2O tCO2e Total CO2e

Total Emissions 0 0 0 0 0

Levied Project Emissions tCO2 tCH4 tN2O tCO2e Total CO2e

P1 - Collection Transfer and Transport of Biomass (diesel) 1,859.2 0.1 0.1 1,878.7

P3 - Processing of Biomass (diesel, propane) 374.9 0.0 0.0 378.8

P12 - Facility Operation (nat gas, diesel, gasoline) 755.7 0.1 0.0 764.9

Total Levied Emission Reductions 2,989.9 0.2 0.1 0.0 3,022.4

Total Non-Eligible Emission Reductions -2,989.9 -0.2 -0.1 0.0 -3,022.4

Other Reported Emissions tCO2 tCH4 tN2O tCO2e Total CO2e


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P20 - Biogenic Caron Emissions 107,910.6 107,910.65

Total Other Reported Emissions 107,910.6 - - - 107,910.65

3.4 Monitoring Plan

The tables below present the details of monitored parameters.

Parameter Monitoring Specifications

Source/sink identifier

and name

B1/P1 – Collection, Transfer and Transport of Biomass

Data parameter Volume of Fuel Diesel

Estimation, modeling,

measurement or

calculation approaches

Measured or estimated using a direct relationship factor

(liters/tonne) as recorded by DAPP or Biofuels for

transport over similar distance to processing of waste

wood respectively.

Data unit L of diesel

Sources/Origin Biomass supplier

Sampling frequency Per load received at Dapp

Description and

justification of

monitoring method

The quantity of diesel fuel used is based on two methods

depending on the third-party activity:

• Independent operators of tractor-trailer units under

contract to Dapp Power: These parties are asked to

indicate total diesel fuel used on Dapp related work for

each month. This information is requested to be

provided with monthly commercial invoices as part of

the contract terms.

Third parties that process (grind, load and transport)

wood biomass and transport directly to the Dapp facility:

These parties deliver wood biomass by their own means

and Dapp pays for a delivered quantity at the plant

gate. Diesel fuel used is based on Dapp & Biofuel’s own

fuel used on a per tonne basis as an estimate. The third

parties use similar equipment to both process and

transport the wood biomass to Dapp and Dapp & Biofuels

combined. Therefore, Biofuels usage is believed to be a

reasonably accurate estimate of fuel usage. Adjustments

may be made if transport logistics vary significantly from

Dapp’s routes used to estimate.


October 2018

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Uncertainty Moderate, fleet efficiency values are a reasonable

representation of actual fuel consumption for collection of

biomass vehicle emissions



and name

B1/P1 – Collection, Transfer and Transport of Biomass

Data parameter EF Diesel CO2, EF Diesel CH4, EF Diesel N2O, GWPCH4, GWPN2O,


measurement or


Reference value

Data unit tCO2/L diesel, tCH4/L diesel, tN2O/L diesel, tCO2/tCH4,

tCO2/tCH4

Sources/Origin Handbook of Emission Factors

Sampling frequency Annual

Description and

justification of

monitoring method

As per offset system guidance

Uncertainty Limited to uncertainty of emission factor supporting data



and name

B3/P3 – Processing of Biomass

Data parameter Volume of Fuel Diesel, Volume of Fuel Propane


measurement or


Measured

Data unit L of diesel & L of Propane

Sources/Origin Biomass supplier – Biofuels Inc.


October 2018

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Sampling frequency Monthly invoices

Description and

justification of

monitoring method

The quantity of diesel fuel used is based on two methods


• Biomass processed through Biofuels: Monthly

invoices for fuel purchases is industry standard and

represents a reasonable level of diligence and

accuracy





gate. Diesel fuel used is based on Dapp & Biofuel’s own

fuel used on a per tonne basis as an estimate. The third




reasonably accurate estimate of fuel usage. Adjustments

may be made if transport logistics vary significantly from

Dapp’s routes used to estimate.

Uncertainty Low, fuel invoices are measured for purchasing and

uncertainty is limited by the fuel vendor



and name


Data parameter EF Diesel CO2, EF Diesel CH4, EF Diesel N2O, GWPCH4, GWPN2O, EF

(electricity)


measurement or


Reference value

Data unit tCO2/L diesel, tCH4/L diesel, tN2O/L diesel, tCO2/tCH4,

tCO2/tCH4 tCO2e/MWh



Description and

justification of

monitoring method

As per protocol


October 2018

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and name


Data parameter Volume of electricity (Biofuels)


measurement or


Measured – EPCOR utility meter

Data unit MWh of Electricity

Sources/Origin Electric utility meter


Description and

justification of

monitoring method

The quantity of electricity used is based on two methods


• Monthly invoices for electricity purchases is

industry standard and represents a reasonable

level of diligence and accuracy. A statement is

received each month from EPCOR for any electricity

metered and recorded as purchased from the grid.





gate. Electricity is based on Dapp & Biofuel’s own fuel

used on a per tonne basis as an estimate. The third




reasonably accurate estimate of fuel usage.

Uncertainty Low, electricity invoices are measured for purchasing and




October 2018

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and name


Data parameter EF Propane CO2, EF Propane CH4, EF Propane N2O


measurement or


Reference value

Data unit tCO2/L, tCH4/L, tN2O/L

Sources/Origin Environment Canada Emission Factors


Description and

justification of

monitoring method

As per protocol




and name

B4/P4 – Fuel Extraction / Processing

Data parameter Volume of Fuel Diesel


measurement or


Measured

Data unit L of diesel

Sources/Origin Biomass supplier


Description and

justification of

monitoring method

Monthly invoices for fuel purchases is industry standard

and represents a reasonable level of diligence and

accuracy




October 2018

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and name

B4/P4 – Fuel Extraction / Processing

Data parameter EF Diesel CO2, EF Diesel CH4, EF Diesel N2O

EF Natural Gas CO2, EF Natural Gas CH4, EF Natural Gas N2O


measurement or


Reference value

Data unit tCO2/L diesel, tCH4/L diesel, tN2O/L diesel

tCO2/m3 natural gas, tCH4/m3 natural gas, tN2O/m3

natural gas



Description and

justification of

monitoring method

As per protocol




and name

B4/P4 – Fuel Extraction Processing

Data parameter Volume of Fuel Natural Gas


measurement or


Measured

Data unit m3 of natural gas

Sources/Origin Pembina Gas Co-operative utility meter - TransCanada

Tap # 4617. (SE1/4 - 32-62-1 W5)



October 2018

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Description and

justification of

monitoring method



accuracy. An invoice is received from the supplier at the

end of each month.





and name

B6 Off-Site Electricity Displaced by Project

Data parameter Volume of Electricity


measurement or


Measured

Data unit kWh

Sources/Origin Utility Meter - PM-9803B004-5 – Midas Metering

downloads data and supplies to TransAlta for invoicing


Description and

justification of

monitoring method

Monthly invoices for electricity generation is industry

standard and represents a reasonable level of diligence

and accuracy

Uncertainty Low, invoices are measured for purchasing and

uncertainty is limited by the utility



and name

B6 Off-Site Electricity Displaced by Project

Data parameter EFEG


measurement or


Reference value - Provided in the Handbook of Emissions

Factors


October 2018

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Data unit tCO2e/MWh



Description and

justification of

monitoring method

As per protocol




and name

B12/P12 – Facility Operations

Data parameter Volume of Fuel Diesel and Volume of Fuel Gasoline


measurement or


Measured

Data unit L of diesel & L of gasoline

Sources/Origin Fuel vendor


Description and

justification of

monitoring method




end of each month. A hard copy of this invoice is kept in

a folder from which the volume will be manually

transposed into the quantification calculator.





and name



October 2018

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Data parameter EF Diesel CO2, EF Diesel CH4, EF Diesel N2O & EF Gasoline CO2, EF Gasoline

CH4, EF Gasoline N2O & EF Natural Gas CO2, EF Natural Gas CH4, EF Natural

Gas N2O


measurement or


Reference value

Data unit tCO2/L diesel, tCH4/L diesel, tN2O/L diesel & tCO2/L

gasoline, tCH4/L gasoline, tN2O/L gasoline & tCO2/m3

natural gas, tCH4/m3 natural gas, tN2O/m3 natural gas



Description and

justification of

monitoring method

As per protocol




and name


Data parameter Volume of Fuel Natural Gas


measurement or


Measured

Data unit m3 of natural gas

Sources/Origin Pembina Gas Co-operative utility meter - TransCanada

Tap # 4617. (SE1/4 - 32-62-1 W5)


Description and

justification of

monitoring method




end of each month.




October 2018

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and name

B15 – Disposal of Biomass

Data parameter Wc


measurement or


Measured

Data unit Tonnes waste

Sources/Origin Weigh scales

Sampling frequency Per load

Description and

justification of

monitoring method

Each truck delivering a load is weighed both full and

empty, thus giving an exact weight of each load of

biomass being delivered to the facility. The weight is

electronically read, and a paper ticket is automatically

printed. These hard copies are kept and then transposed

manually into the quantification calculator. Loads are

tracked by both shipper and source location.

Uncertainty Limited to uncertainty of scales



and name


Data parameter k


measurement or


Calculated

Data unit Unitless

Sources/Origin Emission Factor Handbook



October 2018

Page 25 of 36


Description and

justification of

monitoring method

Methane Generation figure using annual regional

precipitation figures from Environment Canada weather

station

Uncertainty Low, limited to uncertainty of scientific evidence for how

precipitation and evaporation rates affect methane

generation



and name


Data parameter Lo, DOC, DOCf, MCF, F


measurement or


Calculated

Data unit Lo – tonne methane / tonne waste



Description and

justification of

monitoring method

Methane Generation Potential, using wood waste landfill

MCF, and wood waste for DOC and DOCf

Uncertainty Low – since protocol methodology is employed



and name


Data parameter R & OX


measurement or


Estimated using default values

Data unit Percent


October 2018

Page 26 of 36




Description and

justification of

monitoring method

Oxidation Factor default rates of 0.1 and Methane

Collection and Destruction default rates for temporary

covered cells

Uncertainty Low – since protocol methodology is employed



and name


Data parameter EF Biomass CH4, EF Biomass N2O


measurement or


Reference value

Data unit tCH4/MJ or kg, tN2O/MJ or kg

Sources/Origin AP-42


Description and

justification of

monitoring method

As per protocol




and name

P15 – Combustion of Biomass and Fossil Fuels

Data parameter EFBiomass CH4, EFBiomass, N2O


measurement or


Reference value


October 2018

Page 27 of 36


Data unit tCO2/tonne biomass



Description and

justification of

monitoring method

As per protocol


3.5 Data Management System

There are several data collection points for emissions related to diesel consumption. Each of these

points is accounted through one of several emission source/sinks and are depicted in Figure 2: Diesel

Fuel Consumption Data

Diesel fuel is consumed by the DAPP facility, on-site for fuel loading and storage management in

various loaders. Fuel is stored on-site in a tank that is owned by Dapp and Biofuels. Fuel is supplied

by a fuel wholesaler (EFA, Petro Canada, etc.). Fuel is tracked through metering by the fuel

wholesaler when deliveries are made and is invoiced directly to DAPP. Invoices are kept as records

for the project and volume data is manually transcribe into the emission reduction calculation

spreadsheets.

There are several data collection points for emissions related to electricity consumption. Each of

these points is accounted through one of several emission source/sinks and are depicted in

Figure 4: Electricity Production and Consumption Data Management.

Electricity is consumed by the DAPP facility for various electrical loads (lights, office equipment, etc.)

as well as produced through the generator on-site. Electricity production is measured through Midas

on a Schnieder Electric measurement system that is remotely accessed and provided to TransAlta on

a daily basis. TransAlta aggregates the electricity production data and provides DAPP with electricity

purchase invoices on a monthly basis. This meter is net of internal load when producing power. When

the plant is down it records net purchase. During times of no generation and disruption to grid,

internal load is met by backup diesel generation which is recorded as diesel consumption. Invoices

are kept for both the production and consumption of electricity and manually transcribed into the

emission reduction calculator.

Electricity is consumed by the Bio-Fuels Inc. facility for various electrical loads (lights, office

equipment, motors, etc.). Electricity measurement for purchased electricity is through the

utility/retailer EPCOR. The meter is utility owned and operated. Invoices are provided to Biofuels on

a monthly basis which are provided to DAPP and manually transcribed into the emission reduction

calculator.

The data collection points and emissions related to gasoline consumption can be found in Figure 3:

Gasoline Consumption Data Management. Gasoline fuel is consumed by passenger vehicles for site

operations. Fuel is purchased through gasoline retailers at consumer gas stations. Fuel is tracked

through metering by the fuel retailers upon purchase and is invoiced directly to DAPP. Invoices are


October 2018

Page 28 of 36


kept as records for the project and volume data is manually transcribe into the emission reduction

calculation spreadsheets.

The data collection points and emissions related to natural gas consumption can be found in Figure 5:

Natural Gas Consumption Data Management. Natural gas fuel is consumed by the DAPP facility, on-site for

various space heating needs and boiler start-up. Fuel is purchased through Pembina Gas Co-Op on-

site. Fuel is tracked through metering by the utility gas co-op meter on-site and is invoiced directly

to DAPP. Invoices are kept as records for the project and volume data is manually transcribed into

the emission reduction calculation spreadsheets.

The data collection points and emissions related to propane consumption can be found in Figure 6:

Propane Consumption Data Management. Propane fuel is consumed by the Biofuel facility for various space

heating needs and equipment. Fuel is purchased through Superior Propane and is delivered on-site

to a storage bullet. Fuel is tracked through metering by the wholesaler on-site and is invoiced directly

to DAPP. Invoices are kept as records for the project and volume data is manually transcribed into

the emission reduction calculation spreadsheets.

Biomass diverted from landfill and combusted in the project condition contributes to avoided baseline

emissions and is tracked in the baseline emission source/sink demonstrated in Figure 7: Biomass

Diversion Data Management. The figure below depicts the data management for this data stream.

Biomass consumed by the DAPP facility for electricity generation is tracked as it arrives on-site by

weigh-in and weigh-out of delivery trucks. Waste mass is then estimated using weigh scale data,

stock pile data and an energy balance in the calculation spreadsheet. Records for the project and

biomass volume data is manually transcribed into the emission reduction calculation spreadsheets.

Characteristics of the landfills from where waste was diverted is manually transcribed into the

emission reduction calculation spreadsheet based on contractual information and records provided

by waste suppliers.

Meter Maintenance and Calibration

Maintenance and calibration for the metering systems used at the DAPP Generation Facility consists

of a maintenance and calibration program designed to ensure the accuracy of the data collection

system. The details of maintenance and calibration for each meter used in the collection of data for

emission reduction calculations are provided in the table below.

Table 4: Meter Maintenance & Calibration

Project Specific Data

Meter ID Meter Make/

Model Maintenance

Schedule Calibration Schedule

Mass of Biomass Transported to

Dapp

Truck Scale Ancoma Scale Annual third party calibration

Consumption of Natural Gas

Pembina Gas Co-Op

Utility N/A – utility meter

N/A – utility meter

Net Electricity

Generation

PM-

9803B004-5

Schneider Electric

– 7550ION

In-situ test

every 3 years

To be re-verified 6 years after

the initial verification and 5 years after the second re-verification

Steam Production HP Steam Yokogowa/EJA 110A

As Required Annual

Fuel Moisture Analysis Scale

Mass Scale OHAUS Dial-o-gram 1600

As required As Required


October 2018

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Diesel Consumption

EFA, Petro Canada, etc.

Delivery truck meter

N/A – wholesaler meter


Gasoline Consumption

(various retail)

(various retail) N/A – retailer meter

N/A – retailer meter

Bio-Fuels Inc. Propane

Consumption

Superior Propane


N/A – wholesaler

meter


Bio-Fuels Inc. Diesel Consumption

EFA, Petro Canada, etc.




Bio-Fuels Inc.

Electricity Consumption

EPCOR Utility N/A – utility

meter

N/A – utility meter

Quality Assurance and Quality Control

The quantification of the volume of diesel used is completely manual, and is based on monthly

reconciliation of diesel bills. Monitoring and QA/QC for diesel volumes will consist of manual checking

of data entered into the Emission Reduction Calculator against the original diesel bills to ensure

independent review of the data prior to verification. Estimated diesel volumes are also treated

manually.

The quantification of the mass of biomass and volume of natural gas consumed, as well as the

generated is partially manual. Monitoring and QA/QC for biomass consists of annual pile surveys

which requires an independent survey to determine pile volume. Density of fuel is determined

through sampling and a pile mass is established. This mass is compared to the mass received at the

facility and the estimated combusted fuel is subtracted. Any fuel consumption discrepancy which has

accumulated over the period in question is adjusted in the month which the survey was completed

(typically September). At the end of each year, the pile volume is typically reduced to zero which

ensures that the reconciliation process of each year is applicable to that year only and does not

represent inaccuracies of previous years estimations.

Furthermore, the on-site stockpile size is never more than 2 months of fuel. This meets the protocol

requirement for stockpiling less than 90 days (regardless of particle size). The fuel use regime for

the on-site stockpile is ‘first-in-first-out’. This is in the best interest of the plant as the oldest fuel is

inherently drier and therefore the best for combustion. This alignment in interest helps ensures that

no parts of the stockpile remain longer than the 90-day limit and are always combusted prior to

exceeding the storage time limit.

Manual checking will be conducted on an annual basis by a third-party consultant and will consist of:

• Reconciliation of values in the calculator with hard-copy records of electronic data;

• Comparison with data from other time periods to identify any major discrepancies (“reality

checking”); and

• Recalculation of selected values to ensure that the Calculator remains accurate.

Only DAPP employees related to the project have access to the records and calculation files. This

prevents security risks by ensuring only those responsible for delivering project results and only

those with proper credentials are provided access to edit, manipulate or delete information related

to the project. This prevents tampering with project data and improves the reliability of the data

management system.

Record Keeping

Data is collected and managed by several individuals within the organization. Data is collected and

managed to meet operational, financial and commercial needs, including CO2e verification


October 2018

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requirements, Data management procedures exist which are reviewed annually by financial auditors

and CO2e verifier.

Record keeping practices for the project consist of:

• Electronic recording of values of logged primary parameters for each measurement interval;

• Printing of monthly back-up hard copies of all logged data;

• Written logs of operations and maintenance of the project system including notation of all

shut-downs, start-ups and process adjustments;

• Retention of copies of logs and all logged data for a period of 7 years; and

• Keeping all records available for review by a verification body.

.


October 2018

Page 32 of 36


5.0 References

Government of Alberta, 2015. Carbon Offset Emission Factor Handbook, Version 1.0. Specified

Gas Emitters Regulation.

Government of Alberta, 2018. Energy Generation from the Combustion of Biomass Waste, Version

2.2. Carbon Competitiveness Incentive Regulation.

Page 33 of 36


Appendix A: Supporting Information

Figure 2: Diesel Fuel Consumption Data Management

Page 34 of 36

Figure 3: Gasoline Consumption Data Management

Figure 4: Electricity Production and

Consumption Data Management

Page 35 of 36

Figure 5: Natural Gas Consumption Data Management

Figure 6: Propane Consumption Data Management

Page 36 of 36

Figure 7: Biomass Diversion Data Management

Documents

Verdant Energy Ltd - DAPP Power Electricity Generation ... · Verdant Energy Ltd - DAPP Power Electric Generation Facility October 2018 . Page 5 of 36 Version 2.0 Project Plan Form