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Castle Rock Ridge 76 MW Wind Project March 2019

Version 3.0 Report Template – January 2020

Offset Project Report Form Castle Rock Ridge 76 MW Wind Project

Project Developer:

Castle Rock Ridge Limited Partnership

Prepared by: Castle Rock Ridge Limited Partnership

Reporting Period: January 1st to December 31st 2019

Date: March 4, 2019



Greenhouse Gas Assertion

Project Developer:

Castle Rock Ridge Limited Partnership Contact Name: Pascal Brun 1255 University Street, Suite 1204 Montreal, QC, Canada H3B 3W9 Telephone: (514) 397-0463 ext. 224 Website Address Email: [email protected] Project Documents: Title of Offset Project Report: Castle Rock Ridge 76 MW Wind Project Offset Project Report – March 2019 Title of project plan: Castle Rock Ridge 76 MW Wind Project Offset Project Plan – February 2013 Version 3.0 Applicable Protocol, include version and date of protocol. Alberta Environment Quantification Protocol for Wind Powered Electricity Generation (March 2008, Version 1) Project Identification: Project name as it appears on the registry: Castle Rock Ridge 76 MW Wind Project Indicate the reporting period covered by the greenhouse gas assertion and associated project report: January 1st to December 31st 2019 Provide a brief project description: The Project is a 76MW wind energy generation project. The purpose of the Project is to reduce indirect GHG emissions related to the generation of electricity in the province of Alberta through the displacement of grid electricity with renewable, wind-powered electricity generation. Provide the legal land location for the project: The Castle Rock Ridge 76 MW Wind Project is located approximately 3 kilometers north of Pincher Creek, Alberta, Canada and is bounded by the Oldman reservoir to the north. The Project is located within the Municipal District of Pincher Creek No. 9 on the following land parcels: N Sec 21-7-30-4 (Fractional Quarter), SE Sec 1-7-30-4, NW Sec 22- 7-30-4, SW Sec 22-7-30-4, SE Sec 22-7-30-4, NE Sec 15-7-30-4, NW Sec 14-7-30-4, NE Sec 11-7-30-4, NW Sec 1-7-30-4, NE Sec 1-7-30-4, SW Sec 12-7-30-4, SE Sec 14-7-30-4, SE Sec 15-7-30-4, SW Sec 14-7-30-4.



Emission Reduction or Sequestration Assertion:

Vintage Gas Type Quantity (tCO2e)

January 1st to December 31st 2019 CO2 - 318.37

CH4 - 1.09

N2O - 0.11

Total Quantity CO2e 130,411

tCO2e 130,092


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Version 3.0 Report Form – January 2020

Project Developer Signature:

I am a duly authorized corporate officer of the project developer mentioned above and have personally examined and am familiar with the information submitted in this greenhouse gas assertion, the accompanying project report on which it is based. Based upon reasonable investigation, including my inquiry of those individuals responsible for obtaining the information, I hereby warrant that the submitted information is true, accurate and complete to the best of my knowledge and belief, and that all matters affecting the validity of the emission reduction claim or the protocol(s) upon which it is based have been fully disclosed. I understand that any false statement made in the submitted information may result in de-registration of credits and may be punishable as a criminal offence in accordance with provincial or federal statutes.

The project developer has executed this offset project report as of the 3rd day of March, 2020

Signature: ________________________________________

Name: Pascal Brun

Title: President

on 03/03/2020 at 16:49:09 ESTSigned by Pascal Brun


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Table of Contents Greenhouse Gas Assertion .................................................................................................. 2 1.0 Contact Information ............................................................................................ 6 2.0 Project Scope and Site Description ......................................................................... 6

2.1 Project Implementation ........................................................................................ 9 2.2 Protocol ........................................................................................................... 10 2.3 Risks ............................................................................................................... 10

3.0 Project Quantification ........................................................................................ 11 3.1 Summary Table Non-Levied Emissions ................................................................. 11 3.1 Summary Table Levied/Fuel Charge Emissions and Biogenic CO2 .............................. 11 3.2 Calculations ...................................................................................................... 12

4.0 References ....................................................................................................... 18 Appendix A: Supporting Information ................................................................................... 19

List of Tables Table 1: Project Contact Information .................................................................................... 6 Table 2: Project Information ................................................................................................ 6

Instructions are in italics throughout and can be deleted when report is complete. Do not alter the format or template of this document or ‘brand’ it with company logos. Complete report in Verdana 10pt font (no italics) and enter text. If the instruction does not apply to this specific project do not leave blank: enter N/A for not applicable and if practical, provide an explanation of why it is not applicable.

The document is restricted and actions such as ‘insert table’ will not work. PDF’s can be inserted into appendices if needed.

After the report is complete, right click the table of contents and ‘update field’ which will update page numbers in Table of Contents.


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1.0 Contact Information Table 1: Project Contact Information

Project Developer Contact Information Additional Contact Information

Castle Rock Ridge Limited Partnership c/o Enel Green Power North America, Inc.

Castle Rock Ridge Limited Partnership c/o Enel Green Power North America, Inc.

Yurleni Velez

Shirley Sousa

100 Brickstone Square, Suite 300 100 Brickstone Square, Suite 300

Andover, MA 01810

Andover, MA 01810

978-697-5652

351-666-0415

Website Address

Website Address

[email protected] [email protected]

Authorized Project Contact (if applicable)

Company Name Main Contact Name Company Street Address City, Province, Postal Code Telephone number with area code Website Address Email address

2.0 Project Scope and Site Description Table 2: Project Information

Project title Castle Rock Ridge 76 MW Wind Project

Project purpose and objectives

The purpose of the Project is to reduce indirect GHG emissions related to the generation of electricity in the province of Alberta through the displacement of grid electricity with renewable, wind-powered electricity generation.


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Activity start date Turbine commissioning at the Project site commenced on May 23rd,

2012.

Offset start date May 23rd, 2012

Offset crediting period

The Project proponent will claim offsets for a period of 8 years, ending on May 22nd, 2020. After this time, the project will be re-assed for additionally and as circumstances permit, may apply for an additional 5-year extension.

Reporting period covered by the project

January 1st to December 31st 2019

Actual emission reductions/ sequestration

The actual emissions reductions for the Project’s operation for the period of January 1st to December 31st, 2019 is 130,092 tonnes CO2e. The historical emissions reductions for the period of May 23rd, 2012 to December 31st, 2012 were 75,418 tonnes CO2e. The historical emissions reductions for the period of January 1st, 2013 to December 31st, 2013 were 140,742 tonnes CO2e. The historical emissions reductions for the period of January 1st, 2014 to December 31st, 2014 were 131,065 tonnes CO2e. The historical emissions reductions for the period of January 1st, 2015 to December 31st, 2015 were 137,086 tonnes CO2e. The historical emissions reductions for the period of January 1st, 2016 to December 31st, 2016 were 147,918 tonnes CO2e. The historical emissions reductions for the period of January 1st, 2017 to December 31st, 2017 is 149,120 tonnes CO2e. The historical emissions reductions for the period of January 1st, 2018 to December 31st, 2018 is 142,757 tonnes CO2e

Unique site identifier The Castle Rock Ridge 76 MW Wind Project is located approximately 3 kilometers north of Pincher Creek, Alberta, Canada and is bounded by the Oldman reservoir to the north. The Project is located within the Municipal District of Pincher Creek

No. 9 on the following land parcels: N Sec 21‐7‐30‐4 (Fractional Quarter), SE Sec 1‐7‐30‐4, NW Sec 22‐7‐30‐4, SW Sec 22‐7‐30‐4, SE Sec 22‐7‐30‐4, NE Sec 15‐7‐30‐ 4, NW Sec 14‐7‐30‐4, NE Sec 11‐7‐30‐4, NW Sec 1‐7‐30‐4, NE Sec 1‐7‐30‐4, SW Sec12‐7‐30‐4, SE Sec 14‐7‐30‐4, SE Sec 15‐7‐30‐4, SW Sec 14‐7‐30‐4. Latitude: 49.555

Longitude: ‐113.961

Below is a table outlining the 33 wind turbine locations of the Project:


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Wind Turbine Generator Locations Turbine NAD 83 Z12

Number Northing Easting Latitude

(N) Longitude

(W)

1 5496418 283183 49.581443 113.999594

2 5496276 283201 49.580174 113.999267

3 5496151 283268 49.579075 113.998273

4 5495707 283886 49.575308 113.989492

5 5495567 283923 49.574063 113.988904

6 5495423 283936 49.572774 113.988645

7 5495276 283933 49.571453 113.988606

8 5495116 283937 49.570017 113.988463

9 5494968 283964 49.568697 113.988009

10 5494831 284051 49.567498 113.986732

18 5495526 284639 49.573950 113.978992

20 5495177 284718 49.570843 113.977709

21 5495061 284744 49.569811 113.977287

22 5494945 284770 49.568778 113.976864

23 5494695 285133 49.566661 113.971714

24 5494569 285210 49.565557 113.970582

25 5494415 285278 49.564198 113.969559

29 5493951 285471 49.560098 113.966641

30 5493788 285518 49.55865 113.965903

31 5493643 285646 49.557393 113.964057

32 5493512 285713 49.55624 113.96306

33 5493380 285781 49.555079 113.96205

34 5493253 285864 49.553967 113.960835

37 5492925 286054 49.551088 113.958033

38 5492719 286062 49.54924 113.957811

39 5491966 286725 49.54271 113.94825

40 5491814 286824 49.54138 113.946801

41 5491654 286933 49.539981 113.94521

42 5491405 287098 49.537802 113.942798

46 5490904 287434 49.533419 113.93789

47 5490783 287515 49.532361 113.936707

48 5490661 287595 49.531293 113.935537

49 5490514 287694 49.530007 113.934092


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Is the project located in Alberta? Are the emission reductions in Alberta.

Yes

Project boundary The Castle Rock Ridge 76 MW Wind Project is located approximately 3 kilometers north of Pincher Creek, Alberta, Canada and is bounded by the Oldman reservoir to the north.

Ownership The Project is owned by Castle Rock Ridge Limited Partnership (CRRLP), an Alberta limited partnership formed between several wholly owned subsidiaries of Enel Green Power Canada Inc. with the General Partner being Enel Alberta Wind Inc (EAWI). The CRRLP received approval from the Alberta Utilities Commission to construct the Castle Rock Ridge Wind Plant under Decision 2010-58 (Errata).

2.1 Project Implementation The emission offset project was implemented in accordance with the guidance provided in Alberta Environment Quantification Protocol for Wind Powered Electricity Generation (March 2008, Version 1) (Protocol). No flexibility mechanisms are used.

Table 3 in Section 3 Calculations below provides project specific details on how the protocol has been implemented in quantifying emission reductions from the Castle Rock Ridge Wind Power Project and is based on the methodology defined in the Protocol. Minor changes have been made in the calculation procedures, data collection/record keeping, emission factors and some other variables than what has been described in the Offset Project Plan for the 2019 vintage offsets. These minor changes are as follows: O Propane consumed on site has been added. A receipt is supplied by the vendor indicating the weight of propane purchased and the date of purchase. Propane consumption at the Project has been applied to the appropriate monthly total in Greenhouse Gas Quantification Calculations – P1 Facility Operations – Fossil Fuels Consumption – Propane (LBS). • O Greater explanation on invoicing periods by the third-party service provider EPCOR has been added. A table has been added to the Project Workbook detailing the electricity consumption of the Substation Building and O&M Building on a calendar month. For each bill received, the billing period is for a period of the 8th to the end of the calendar month. The 1st to the 7th is found on the previous months invoice. The table P1-EPCOR reconciles the billing period to the 1st to the last day of the calendar month. • O Greater explanation on invoicing periods by the third-party service provider AltaGas has been added. A table has been added to the Project Workbook detailing the fossil fuel consumption on a calendar month. For each bill received, the billing period is for a period of the 1st to the 23rd of the calendar month. The 23rd to the end of the month is found on the next month’s invoice. The table P1-AltaGas reconciles the billing period for the 1st to the last day of the calendar month.


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• O Greater explanation on SF6 disclosure. According to the SF6 breaker manufacturer, the SF6 circuit breakers are manufactured to be a closed gas system with a very low leakage rate. When the circuit breaker operates (Open or Close) the gas is used as the insulation medium and the quenching of the arc. Over the life span of the circuit breaker, there should be no gas loss. • O In July 2014 the Project changed its purchasing for the volume of gasoline consumed on site by the one service truck. It no longer uses one single vendor but uses all available vendors. A receipt is supplied by the vendor indicating the volume of gasoline purchased and the date of purchase. The volume of gasoline is applied to the appropriate monthly total in Greenhouse Gas Quantification Calculations - P1 Facility Operations - Fossil Fuels Consumption – Gasoline (L). The reporting period addressed by this document is January 1st, 2019 to December 31st, 2019 (inclusive). 2012 was the first year of Project operations. Following 2012, the reporting period will be for full calendar years starting January 1st ending December 31st of each vintage year. The 2019 vintage verification is Internat Energy Solution Canada Inc.’s third for the Project.

2.2 Protocol Alberta Environment Quantification Protocol for Wind Powered Electricity Generation (March 2008, Version 1) No flexibility mechanisms are used. The Project is located in Alberta, generates electricity from wind, and connects to the Alberta Integrated Electricity System. The Project complies with the quantification protocol Alberta Environment Quantification Protocol for Wind Powered Electricity Generation (March 2008, Version 1). The Project uses this Protocol to meet the measurement, monitoring and GHG quantification requirements for reductions from the electricity generated at Castle Rock Ridge 76 MW Wind Project. The Project also aligns with all applicability requirements stated in the quantification protocol. Specifically:

1. Metering of net electricity generation occurs at a point downstream of generation at the point of interconnection with the electricity grid; and

2. Emission reductions are quantified based on actual measurements and monitoring.

2.3 Risks There are a number of sources of risk to the regular Projects operations. Wind powered electricity generation projects are dependent on the proper functioning of the revenue meter to calculate the Greenhouse Gas Offset Credits generated by the Project. The risk of metering failure is mitigated by the maintenance and calibration procedures of the project.


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The Project is required to follow industry practices while under regular operations. There are environmental monitoring requirements with the Fish and Wildlife Division of Alberta Environment and Sustainable Resource Development as well as with Natural Resources Canada that will be undertaken for the first 2 years of the project life. These potential impacts have been mitigated by undertaking the appropriate pre-construction risk assessment and consultation with the regulatory agencies.

3.0 Project Quantification 3.1 Summary Table Non-Levied Emissions

Vintage Gas Type Baseline Emissions

Project Emissions

Total Reduction, Sequestration, or Capture

2019 CO2 n/a 297.63 -297.63

2019 CH4 n/a n/a n/a

2019 N2O n/a n/a n/a

2019 Other (CO2e)

130,411 n/a 130,411

Total 2019 CO2e 130,411 tCO2e 297.63 tCO2e 130,113.74 tCO2e

Total for Reporting Period

CO2e 130,411 tCO2e 297.63 tCO2e

130,113.74 tCO2e

3.1 Summary Table Levied/Fuel Charge Emissions and Biogenic CO2

Vintage Gas Type Baseline

Emissions

Project

Emissions

Total Reduction,

Sequestration, or

Capture

2019 CO2 n/a 20.73 -20.73

2019 CH4 n/a 1.09 -1.09

2019 N2O n/a 0.11 -0.11


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2019 Other (CO2e) n/a n/a n/a

Total 2019 CO2e n/a 21.87 tCO2e -21.87 tCO2e

Total for

Reporting

Period

CO2e n/a 21.87 tCO2e -21.87 tCO2e

Total Levied & Non-Levied Emissions for Reporting Period

CO2e 130,411 tCO2e

319.51 tCO2e 130,092 tCO2e

3.2 Calculations Section 4 of the Alberta Quantification Protocol for Wind-Powered Electricity Generation defines the appropriate methodology in quantifying emission reductions from wind power projects. The

following three equations serve as the basis for calculating the emission reductions from the Project, using the emission profiles of the baseline and project conditions. Note that only SSRs determined to be relevant to this Project are included here. Emissions Baseline = Emissions Electricity Generation Emissions Project = Emissions Facility Operation + Emissions Fuel Extraction & Processing Emission Reduction = Emissions Baseline − Emissions Project Data Inputs 2019 Conversion 2019 Converted Net Electricity Production (MWh) 200,632.8846 N/A 200,632.8846 MWhGasoline Consumption (L) 2,144.70 N/A 2,144.70 L Propane Consumption (LBS) 33 453.59g/LB, 493 g/L 30.36 L Natural Gas Consumption (GJ) 281.12 26.853 m3/GJ 7,548.92 m3 Electricity Consumed (kWh) 338,219.80 N/A 338,219.80 kWh

Calculations: Emissions from Facility Operations and Fuel Extraction & Processing B1 Electricity Generation Baseline tCO2 = Electricity * EFElectricity


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P1 Facility Operations EmissionsP1 tCO2e= Σ (VolFueli * FueliEFCO2) + Σ (VolFueli * FueliEFCH4) *GWPCH4+ Σ (VolFueli * FueliEF N2O)* GWPN20 + ΣElectricityConsumed * EFElectricity Consumption P3 Fuel Extraction and Processing EmissionsP3 tCO2e = Σ (VolFueli * FueliEFCO2) + Σ (VolFueli * FueliEFCH4) *GWPCH4+ Σ (VolFueli * FueliEF N2O)* GWPN20 No flexibility mechanisms were used. Table 3 below provides project specific details on how the protocol has been implemented in quantifying emission reductions from the Castle Rock Ridge Wind Power Project and is based on the methodology defined in the Protocol.

Table 3. Measurement and Estimation Procedures for Each Quantification ParameterProtocol Parameter / Variable

Project‐specific data

Measurement or Estimation Procedure

Measurement Frequency

Measurement Specifications or Estimation Justifications

B1 Electricity Generation

Incremental Electricity Exported from the Site

Net electricity generation data from AESO settlement statements and historic generation reports

Direct metering of net transfer of electricity to and from the grid.

Continuous (Measured in 15 minute increments)

Data is collected from AESO Settlement Statements where Production is net of any consumption when the facility is producing power. Meter Identification: Identifier: CASTLEROCKRDG.T1 Serial#: PJ‐1012A192‐02 The revenue electricity meter was changed in September 2016 Meter Identification: Identifier: CASTLEROCKRDG.T1 Serial#: PJ‐1606A336‐04

GHG Emission Factor for Electricity Generation

0.65 t CO2e / MWh

As stated in the Guide. N/A Grid displacement factor sourced from the AlbertaEnvironment Technical Guidance for Offset Protocol Developers (January 2011, Version 1.0), page 33.

P1 Facility Operations

Power consumed on site.

Volume of electricity supplied by EPCOR to the substation building and the O&M Office Building and Substation building

Direct metering of electricity from the grid

Continuous EPCOR Meter Numbers: O&M Office Building Address: 111 1 Deere Ave, Pincher Creek, AB Site: 40000729982 Meter: 000000000001380622 As of August 23, 2018, the O&M Office Building address changed to: Address: 1052 Elk Ave, Pincher Creek, AB Site: 40001114476 Meter: 000000000001381883


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The billing period is set by the vendor. The invoices for electricity consumption used to quantify O&M building electricity use are for January 1st, 2019 to December 31st, 2019. Substation Building Address: SE‐14‐007‐30‐4; MD of Pincher Creek No. 9 Site: 40001203427 Meter: 000000000001425833 The billing period is set by the vendor. Volume of electricity supplied by EPCOR Energy to the substation building. From Monthly EPCOR Invoices. Negative values on invoices indicate dollar credits reimbursed to CRRLP. The billing period is from January 1st, 2019 to December 31st, 2019.

Power consumed on site.

Volume of electricity supplied by EPCOR to the Project through the Transmission system

Direct metering of electricity from the grid

Continuous (Measured in 15 minute increments)

Data is collected from AESO Settlement Statements to retrieve electricity consumption from the Project. This is the consumption of the facility when the Project does not have any production. Meter Identification: Identifier: CASTLEROCKRDG.T1 Serial#: PJ‐1012A192‐02 The revenue electricity meter was changed in September 2016 Meter Identification: Identifier: CASTLEROCKRDG.T1 Serial#: PJ‐1606A336‐04

GHG Emission Factor for Electricity Consumption (Generation Intensity)

0.88 t CO2e / MWh

As stated in National Inventory Report and recommended by Alberta Environment.

N/A 2008 Electricity Intensity Factors, National Inventory Report, email from AESRD dated 2014‐01‐28.

Fossil fuels consumed on site.

Volume of gasoline consumed on site.

Based on fuel procurement records from regulated fuel pumps.

Recorded under monthly tallies.

Fuel procurement records are collected as refueling occurs. In July 2014 the Project changed its purchasing for the volume of gasoline consumed on site by the one service truck. A receipt is supplied by the vendor indicating the volume of gasoline purchased and the date of purchase. The volume of gasoline is applied to the appropriate monthly total.


Volume of diesel consumed on site.

Based on fuel procurement records from regulated fuel pumps. Diesel fuel is not consumed by equipment used in the operations of the Project.


Fuel procurement records are collected as refueling occurs.


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GJ of natural gas consumed on site.

Based on utility invoices generated from metered consumption on site at the O&M Building.


The billing period is set by the vendor. Utility invoices are received on a monthly basis. The billing period is from January 1st, 2019 to December 31st, 2019.


Pounds of propane consumed on site.

Based on fuel procurement records from regulated fuel pumps.



CO2 emission

factor

for gasoline

combustion

2,289g CO2 / L The fuel consumed at the site

was uniquely for the

operations of the project’s

service trucks (2011 Ford F‐

150).

N/A

Canada National Inventory Report 1990 to 2012 Part 2 Table A8‐11 Emission Factors for Energy Mobile Combustion Sources; Light‐duty Gasoline Trucks (LDGTs), Tier 2

CH4 emission factor for gasoline

0.14g CH4 / L N/A

N2O emission factor for gasoline combustion

0.022 g N2O/

L

N/A

CO2 emission factor for diesel combustion

2,663 g CO2/ L Diesel fuel is not consumed

by equipment used in the

operations of the Project.

N/A Canada National Inventory Report 1990 to 2012

Part 2 Table A8–11 Emission Factors for Energy

Mobile Combustion Sources, Heavy Duty Diesel

Vehicles (HDDVs) Uncontrolled

CH4 emission

factor for

diesel

combustion

0.15 g CH4 / L N/A

N2O emission

factor for

diesel

combustion

0.075 g N2O/L N/A

CO2 emission factor for natural gas combustion

1,918 g CO2/m3

Based on utility invoices generated from metered consumption on site at the O&M Building.

Monthly Canada National Inventory Report 1990 to 2012 Part 2 Table A8‐2 CH4 Emissions Factors for Natural Gas; Industrial

CH4 emission factor for natural gas combustion

0.037 g CH4/m3

Based on utility invoices generated from metered consumption on site.

Monthly

N2O emission factor for natural gas combustion

0.033 g N20/m3


Monthly


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Conversion

factor for

natural gas

(GJ to m3)

26.853 m3/GJ Natural Resources Canada, Natural Gas

Information for Consumers, Natural Gas

Conversion Factors.

http://www.nrcan.gc.ca/energy/natural‐gas/5641

CO2 emission factor for propane combustion

1507 g CO2/L Based on fuel procurement records.

Monthly Canada National Inventory Report 1990 to 2012

Part 2 Table A8‐11 Emissions Factors for Energy

Mobile Combustion Sources; Propane Vehicles

CH4 emission factor for propane combustion

0.64 g CH4/L Based on fuel procurement records.




N2O emission factor for propane combustion

0.028 g N2O/L Based on fuel procurement records.




Propane

Density

493 g/L Razmi, Amir (May 2019). "Propylene Production by

Propane Dehydrogenation (PDH)". Engineering: 3.

P3 Fuel Processing & Extraction

Fossil fuels consumed on site

Volume of gasoline consumed on site.

Based on fuel procurement records.




Volume of diesel consumed on site.





GJ of natural gas consumed on site.



Utility invoices are received on a monthly basis.

CO2 emission factor for gasoline production

138 g CO2 / L Based on fuel procurement records.

N/A CO2, CH4, and N2O Emission Factors for gasoline production, as listed in Alberta Wind Power Electricity Generation Protocol, March 2015, Page 7. http://aep.alberta.ca/climate‐change/guidelines‐legislation/specified‐gas‐emitters‐regulation/documents/CarbonEmissionHandbook‐Mar11‐2015.pdf

CH4 emission factor for gasoline production

10.9 g CH4 / L Based on fuel procurement records.

N/A CO2, CH4, and N2O Emission Factors for gasoline production, as listed in Alberta Wind Power Electricity Generation Protocol, March 2015, Page 7. http://aep.alberta.ca/climate‐change/guidelines‐legislation/specified‐gas‐emitters‐


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regulation/documents/CarbonEmissionHandbook‐Mar11‐2015.pdf

N2O emission factor for gasoline production

0.004 g N2O/ L



CO2 emission factor for diesel production

138 g CO2/ L Based on fuel procurement records.


CH4 emission factor for diesel production

10.9 g CH4 / L Based on fuel procurement records.


N2O emission factor for diesel production

0.004 g N2O/L Based on fuel procurement records.


CO2 emission factor for natural gas extraction

43 g CO2/ m3 Based on utility invoices generated from metered consumption on site.


CH4 emission factor for natural gas extraction

2.3 g CH4/m3 Based on utility invoices generated from metered consumption on site.

NA CO2, CH4, and N2O Emission Factors for gasoline production, as listed in Alberta Wind Power Electricity Generation Protocol, March 2015, Page 7. http://aep.alberta.ca/climate‐change/guidelines‐legislation/specified‐gas‐emitters‐regulation/documents/CarbonEmissionHandbook‐Mar11‐2015.pdf

N2O emission factor for natural gas

0.004 g N20/m3


N/A CO2, CH4, and N2O Emission Factors for gasoline production, as listed in Alberta Wind Power


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extraction Electricity Generation Protocol, March 2015, Page 7. http://aep.alberta.ca/climate‐change/guidelines‐legislation/specified‐gas‐emitters‐regulation/documents/CarbonEmissionHandbook‐Mar11‐2015.pdf

CO2 emission factor for natural gas processing

90 g CO2/ m3 Based on utility invoices generated from metered consumption on site.


CH4 emission factor for natural gas processing

0.3 g CH4/m3 Based on utility invoices generated from metered consumption on site.


N2O emission factor for natural gas processing

0.003 g N20/m3



4.0 References Include references. Author, Year, Title.

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Appendix A: Supporting Information