ghost pine wind power project - csaregistries.ca

Ghost Pine Wind Power Project February 2019

Version 2.0 Report Template – July 2018

Greenhouse Gas Assertion

Project Developer:

Company Name Fortuna GP, ULC Contact Name Michael Sheehan Company Street Address 700 Universe Blvd, Juno Beach Office City, Province, Postal Code Juno Beach, Florida, USA 33408 Telephone number with area code (561) 691-7887 Website Address www.nexteraenergy.com Email address [email protected] Project Documents: Title of Offset Project Report Offset Project Report for Ghost Pine Wind Power Project Title of project plan, date of project plan, revised project plan and date (if applicable) Offset Project Plan for Ghost Pine Wind Power Project, November 2015, Version 1.7 Applicable Protocol, include version and date of protocol. Alberta Environment & Parks Quantification Protocol for Wind Powered Electricity Generation (March 2008, Version 1) Project Identification: Project name as it appears on the registry Ghost Pine Wind Power Project Project Identifier: 4852-9626 Indicate the reporting period covered by the greenhouse gas assertion and associated project report November 1, 2018 through December 31, 2018 Provide a brief project description.

The Project is located in Kneehill County, Alberta. 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.

Ghost Pine Wind Power Project – Offset Project Report January 2019

APPENDIX A – Supporting Information 1

APPENDIX A: SUPPORTING INFORMATION DETAILED INFORMATION ON GHG QUANTIFICATION METHODOLGY Section 4 of the Alberta Quantification Protocol for Wind-Powered Electricity Generation defines the appropriate methodology in quantifying emission reductions from wind power projects. Table 1 below provides project specific details on how the protocol has been implemented in quantifying emission reductions from the Ghost Pine Wind Power Project and is based on the methodology defined in the Protocol. No flexibility mechanisms were applied in the quantification of GHG reductions for this crediting period. No emission factors have been updated since the crediting start date to maintain baseline stability and consistency between each reporting period. Table 1: Measurement and Estimation Procedures for Each Quantification Parameter Protocol 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: GHOSTPINE.T1_HI Serial # PJ-1011A028-02

GHG Emission Factor for Electricity Generation

0.65 t CO2e / MWh As stated in the Guide. N/A Grid displacement factor sourced from the Alberta Environment & Parks 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 Direct Energy to the substation building and the operations and maintenance building.

Direct metering of electricity from the grid

Continuous Direct Energy Meter Number: 107705-00000027/Serial Number K07705-81932603 (O&M building) 107705-00000028/ K07705-81930957 (substation building)



Table 1: Measurement and Estimation Procedures for Each Quantification Parameter Protocol Parameter / Variable




Power consumed on site.

Volume of electricity supplied by Direct Energy 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: GHOSTPINE.T1_HI Serial # PJ-1010A760-02

GHG Emission Factor for Electricity Consumption

0.88 t CO2e / MWh As recommended by Alberta Environment & Parks

N/A As recommended by Alberta Environment & Parks

Fossil fuels consumed on site.

Volume of gasoline consumed on site determined by using tracked fuel purchases

Based on fuel procurement records from regulated fuel pumps.

Fuel consumption is recorded at each refueling event.

NextEra’s fleet management system is referenced to determine the total amount of fuel consumed by vehicles on site for each reporting period. Information is electronically transferred to the system during each transaction, where, the fuel pump is the source of information on how much fuel is dispensed. Fuel pumps are governed under Provincial laws, where tampering is considered an act of fraud, as such, these are considered the best sources of accurate data.

Volume of diesel consumed on site.

Same approach as noted above for gasoline.

Same as above Same as above

GJ of natural gas consumed on site.

Based on utility invoices generated from metered consumption on site.

Recorded under monthly tallies.

Utility invoices are received on a monthly basis. Meter Serial #: 15C764708







CO2 emission factor for gasoline combustion

2,289g CO2 / L Fuel procurement records do not always specify which piece of equipment was fueled. Currently, there is a mix of gasoline vehicles and generators. Although it is difficult to distinguish the use of the gasoline procured, it is assumed that the majority of fuel consumed is for the light-duty gasoline trucks.

N/A Table A8-11, Emission Factors for Energy Mobile Combustion Sources, National Inventory Report 1990–2012—Part 2, Page 188 (Tier 2, Vehicles from 2004 to 2009) http://unfccc.int/files/national_reports/annex_i_ghg_inventories/national_inventories_submissions/application/zip/can-2014-nir-11apr.zip

CH4 emission factor for gasoline

0.14g CH4 / L N/A

N2O emission factor for gasoline combustion

0.022g N2O/ L N/A

CO2 emission factor for diesel combustion

2,663 g CO2/ L Based on fuel procurement records. Fuel procurement records do not specify which piece of equipment was fueled. As it is difficult to distinguish the use of the diesel procured, it is assumed that the majority of fuel consumed is for the light-duty gasoline trucks, therefore, the most conservative emission factor in that category is used.

N/A Table A8-11, Emission Factors for Energy Mobile Combustion Sources, National Inventory Report 1990–2012—Part 2, Page 188 (Heavy Duty Diesel Vehicles, Uncontrolled) http://unfccc.int/files/national_reports/annex_i_ghg_inventories/national_inventories_submissions/application/zip/can-2014-nir-11apr.zip

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


Monthly Table A8-1, CO2 Emission Factors for Natural Gas, Alberta Marketable Table A8-2, CH4 and N2O Emission Factors for Natural Gas, Commercial/Institutional National Inventory Report 1990–2012—Part 2, Pages 183 and 184)

CH4 emission factor for natural gas combustion

0.037 g CH4/m3

http://unfccc.int/files/national_reports/annex_i_ghg_inventories/national_inventories_submissions/application/zip/can-2014-nir-11apr.zip












N2O emission factor for natural gas combustion

0.035 g N20/m3 http://unfccc.int/files/national_reports/annex_i_ghg_inventories/national_inventories_submissions/application/zip/can-2014-nir-11apr.zip

Conversion factor for natural gas (GJ to m3)

26.8 m3/GJ Natural Resources Canada, Natural Gas Information for Consumers, Natural Gas Conversion Factors. http://www.nrcan.gc.ca/eneene/sources/natnat/infinf-eng.php Also, ATCO Energy Sense (http://www.atcoenergysense.com/Tools+and+Resources/Tools+and+Publications/Residential/EnergyConversionTable.htm) *The conversion factor is approximate. Converting gas volumes to energy is estimated, and not exact, as the energy content of natural gas varies slightly depending on the precise composition of the gas.

P3 Fuel Processing & Extraction Fossil fuels consumed on site

Volume of gasoline consumed on site.

Based on fuel procurement records.


Fuel procurement records are collected as refueling occurs.

Volume of diesel consumed on site.

Based on fuel procurement records.


Fuel procurement records are collected as refueling occurs.

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 2008, Page 21. http://environment.gov.ab.ca/info/library/7933.pdf




http://www.nrcan.gc.ca/eneene/sources/natnat/infinf-eng.php

http://www.nrcan.gc.ca/eneene/sources/natnat/infinf-eng.php

http://www.atcoenergysense.com/Tools+and+Resources/Tools+and+Publications/Residential/EnergyConversionTable.htm



http://environment.gov.ab.ca/info/library/7933.pdf








CH4 emission factor for gasoline production

10.9 g CH4 / L N/A

N2O emission factor for gasoline production

0.004 g N2O/ L N/A

CO2 emission factor for diesel production

138 g CO2/ L N/A CO2, CH4, and N2O Emission Factors for diesel production, as listed in Alberta Wind Power Electricity Generation Protocol, March 2008, Page 21. http://environment.gov.ab.ca/info/library/7933.pdf

CH4 emission factor for diesel production

10.9 g CH4 / L N/A

N2O emission factor for diesel production

0.004 g N2O/L N/A

CO2 emission factor for natural gas extraction

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

N/A CO2, CH4, and N2O Emission Factors for natural gas extraction and processing, as listed in Alberta Wind Power Electricity Generation Protocol, March 2008, Page 21. http://environment.gov.ab.ca/info/library/7933.pdf

CH4 emission factor for natural gas extraction

2.3 g CH4/m3 N/A

N2O emission factor for natural gas extraction

0.004 g N20/m3 N/A











CO2 emission factor for natural gas processing

90 g CO2/ m3 N/A

CH4 emission factor for natural gas processing

0.3 g CH4/m3 N/A

N2O emission factor for natural gas processing

0.003 g N20/m3 N/A



Table 2: Sample Quantification (For one Month) SSR Parameter Equation Sample Calculation and Result B1 Electricity Generation

Total Emissions from SSR

Emissions B1 = Net Exports of Electricity * EFElectricity Emissions B1 = [18,443,644.40] * [0.65 kg CO2e /kWh] = 11,988,368.86 kg CO2e

Total Baseline Scenario Emissions: 11,988,368.86 kg CO2e P1 Facility Operations


Emissions P1 = Imports of Electricity * EFElectricity Consumption Emissions Electricity Consumption = [35,359.27 kWh] * [0.88] kg CO2e /kWh] = 31,116.16 kg CO2e

P1 Facility Operations


CO2 EmissionsP1 = [Volume of Diesel * Diesel EF Combustion CO2] CH4 EmissionsP1 = [Volume of Diesel * Diesel EF Combustion CH4 * GWPCH4] N2O EmissionsP1 = [Volume of Diesel * Diesel EF Combustion N20 * GWPN2O]

CO2 EmissionsP1Diesel = ([90 L] * [2,663 g CO2/ L])/ 1,000 g/kg + CH4 EmissionsP1Diesel = ([90 L] * [0.15 g CH4 / L] * [25]) / 1,000 g/kg + N2O EmissionsP1 Diesel= ([90 L] * [0.075 g N2O/L] * [298]) / 1,000 g/kg TOTAL = 242.02 kg CO2E

CO2 Emissions P1 = [Volume of Gasoline * Gasoline EF Combustion CO2] CH4 Emissions P1 = [Volume of Gasoline * Gasoline EF Combustion CH4 * GWPCH4] N2O Emissions P1 = [Volume of Gasoline * Gasoline EF Combustion N20 * GWPN2O]

CO2 Emissions P1Gasoline = ([307.7 L] * [2,289g CO2 / L]) /1,000 g/kg + CH4 Emissions P1 Gasoline = ([307.7 L] * [0.14g CH4 / L] * [25]) / 1,000 g/kg + N2O Emissions P1 Gasoline = ([307.7 L] * [0.022g N2O/ L] * [298]) / 1,000 g/kg TOTAL = 707.42 kg CO2e

CO2 Emissions P1 = [GJ of Natural Gas Combusted * Natural Gas Energy to Volume Conversion Factor * Natural Gas EF Combustion CO2] CH4 Emissions P1 =

CO2 Emissions P1 = ([75.92 GJ]*[26.8 m3/GJ]*[1,918 g CO2/ m3])/1,000 g/kg + CH4 Emissions P1 =



[GJ of Natural Gas Combusted * Natural Gas Energy to Volume Conversion Factor * Natural Gas EF Combustion CH4 * GWPCH4] N2O Emissions P1 = [GJ of Natural Gas Combusted * Natural Gas Energy to Volume Conversion Factor * Natural Gas EF Combustion N2O * GWPN20]

([75.92 GJ]*[26.8 m3/GJ] * [0.037 g CH4/m3])*25)/1,000 g/kg) + N2O Emissions P1 = ([75.92 GJ]*[26.8 m3/GJ]*([0.035 g N20/m3])*298)/1,000 g/tonne TOTAL = 3,925.57 kg CO2e

P3 Fuel Extraction and Processing


CO2 Emissions P3 = [Volume of Diesel * Diesel EF Production CO2] CH4 Emissions P3 = [Volume of Diesel * Diesel EF Production CH4 * GWPCH4] N2O Emissions P3 = [Volume of Diesel * Diesel EF Production N20 * GWPN2O]

CO2 Emissions P3Diesel = ([90 L] * [138 g CO2/ L] )/1,000 g/kg) + CH4 Emissions P3Diesel = ([90 L] * [10.9 g CH4 / L] * [25] )/1,000g/kg) + N2O Emissions P3Diesel = ([90 L] * [0.004 g N2O/L] *[298] )/1,000 g/kg) TOTAL = 37.13 kg tonnes CO2e

CO2 Emissions P3 = [Volume of Gasoline * Gasoline EF Production C O2] CH4 Emissions P3 = [Volume of Gasoline * Gasoline EF Production C H4 * GWPCH4] N2O Emissions P3 = [Volume of Gasoline * Gasoline EF Production N20 * GWPN2O]

CO2 Emissions P3 Gasoline = ([307.70 L] * [138 g CO2/ L])/1,000 g/tonne) + CH4 Emissions P3 Gasoline = ([307.70 L] * [10.9 g CH4 / L] * [25])/1,000 g/tonne) + N2O Emissions P3 Gasoline = ([307.70 L] * [0.004 g N2O/L] * [298])/1,000 g/tonne) TOTAL = 126.96 kg CO2e

CO2 Emissions P3 = [GJ of Natural Gas Combusted * Natural Gas Energy to Volume Conversion Factor * [Natural Gas EF Extraction CO2 + Natural Gas EF Processing CO2] CH4 Emissions P3 =

CO2 Emissions P3 = ([75.92 GJ]*[26.8 m3/GJ]*([43 g CO2/m3]+[90g CO2/ m3])/1,000 g/tonne) CH4 Emissions P3 = ([75.92 GJ]*[26.8 m3/GJ] * ([2.3 g CH4/m3]+[3.0 g CH4/m3]) *25)/1,000 g/tonne)



Summary: Emissions Baseline 11,988,368 kg CO2e

Emissions Project 36,564 kg CO2e

Emission Reduction = EmissionsBaseline - EmissionsProject = 11,988,368 kg CO2e – 36,564 kg CO2e / 1,000 kg/tonne = 11,951 tonnes CO2e

[GJ of Natural Gas Combusted * Natural Gas Energy to Volume Conversion Factor * [Natural Gas EF Extraction CH4, + Natural Gas EF Processing C H4 ]* GWPCH4] N2O Emissions P3 = [GJ of Natural Gas Combusted * Natural Gas Energy to Volume Conversion Factor * [Natural Gas EF Extraction N20 + Natural Gas EF Processing N20 ]* GWPN2O]

N2O Emissions P3 = ([75.92 GJ]*[26.8 m3/GJ]*([0.004 g N20/m3]+[0.003 g N20/m3])*298)/1,000 g/tonne TOTAL = 408.96 kg CO2e

Total Project Scenario Emissions (Rounded Up) = 36,564.2 kg CO2e



Project Monitoring Plan

The following sections detail the monitoring plan for each parameter required for the quantification of emission reductions. Data collection and management process flow diagrams for each parameter are included below.

As described in greater detail in Sections 3.4.1, 3.4.2, and 3.5, there are multiple steps to data collection, validation, and verification that are instituted to support the GHG emissions reduction quantification and offset serialization process.

With regards to net-electricity exports, which constitutes the most material sources of emissions in quantifying GHG emissions reductions:

1. Metering of net electricity generation occurs at a point downstream of generation at the point of interconnection with the electricity grid. The electricity produced for the facility is measured by a revenue meter before the energy is injected into the power pool. Electricity consumed by the turbines for the purposes of heating and lighting is netted out of the energy produced;

2. Turbine performance is continuously monitored by operations staff, with data collected and stored through a Supervisory Control and Data Acquisition (SCADA) system;

3. Information from the SCADA system is compared to the electricity export meter to ratify settlements by the Alberta Electric System Operator (AESO);

4. Data collected from a second meter upstream of the substation is also referenced to ratify electricity export settlements;

5. Emission reductions are quantified based on actual measurements and monitoring – As mentioned above, the energy produced by the facility is measured. The meters are regularly checked for accuracy and corrected as necessary;

6. Historical production data and experience also constitute another measure of data validation; 7. Any discrepancies are investigated by facility operations and Rodan Energy Solutions within the

timeframe specified by the AESO Settlement Process.

With regards to facility operations and fuel extraction and processing:

1. Energy commodities (including electricity, natural gas, diesel and gasoline) are all measured using revenue class metering systems which are regularly checked for accuracy and corrected as necessary;

2. Data transfer from metering devices to utility and fuel procurement statements is automated; 3. Energy consumption is also evaluated against historical consumption trends and reviewed by

facility operations and the emissions reduction quantification team for accuracy; and 4. Although utility statement data is manually compiled into an energy consumption log (Excel), the

data entry is reviewed through multiple validation processes by the quantification team. 5. Quantification calculators, reports, and assertions are all reviewed and verified by a qualified

third-party, in accordance with Standards for Validation, Verification and Audit, Version 3.0, December 2018.



Net Electricity Exported

Electricity, net of any onsite consumption, is exported from the Project to the transmission grid. Associated emissions are accounted for by a single parameter, B1 Electricity Generation

1 Alberta Utilities Commission, Rule 021, Version 2.1, Settlement System Code Rules http://www.auc.ab.ca/acts-regulations-and-auc-rules/rules/Documents/Rule021.pdf

Table 3: Monitoring Plan for Net Electricity Exported Source / Sink Identifier or Name

B1 Electricity Generation

Data parameter Net Electricity exported to the grid. Estimation, Modeling, Measurement or Calculation approaches

The Project Developer has contracted the services of a third-party metering services provider (Rodan Energy) to monitor and manage meter data. The metering services provider is registered with the Alberta Electricity System Operator as a Metering Data Provider/Manager and are subject to the Alberta Utility Commission’s Settlement System Code (Rule 021)1 All measurements of electricity exports from the Project are net of any electricity consumed by onsite systems such as the turbines and the meteorological tower when the wind farm is producing power.

Data Unit MWh Sources / Origin Direct measurement through revenue quality meter. Monitoring Frequency Meter is read in 15-minute increments and reported

hourly. Description and Justification of Monitoring Method

AESO settlement data is the most accurate information related to net electricity exports as this information is governed by the Alberta Utility Commission’s Settlement System Code which defines rules for measuring, monitoring, and verification of all settlement data submitted to the AESO. Generation data is communicated to the AESO through an automated data transfer protocol. The metering services provider polls all revenue meters remotely every day to check/sync the meters clock and then extract and store the interval data from the meter’s internal recorder to a database managed by the metering services provder.

http://www.auc.ab.ca/acts-regulations-and-auc-rules/rules/Documents/Rule021.pdf



2 AESO Measurement System Standard, http://www.google.ca/url?q=http://www.aeso.ca/downloads/AESO_Measurement_System_Standard(2).pdf&sa=U&ei=e-elTor7LKqPigKi0JDODQ&ved=0CBIQFjAA&usg=AFQjCNFw3SaEPWAeM021nkaLbcOREmegKA 3 AESO SCADA Standard, http://www.aeso.ca/downloads/SCADA_Standard_Final.pdf 4 AESO Settlement Process Guide, http://www.aeso.ca/downloads/AESO_Settlement_Process_Guide.pdf

Once the metering data has passed validation, the data is aggregated as per the AESO’s measurement point definition and then transferred electronically to the AESO.

Electricity meters are all governed under the Weights and Measurements Act of Canada (Current, 2011-09-21) with specific regulations and procedures defined for the calibration and monitoring of such revenue class meters.

Net Electricity Exports from the Project were determined by referencing AESO Final Pool Statements. These are listed under “ENERGY PAYMENTS” in the “PRODUCTION” section of the statement. These were also verified by pulling the AESO online, historic generation database was accessed to retrieve generation data, which is available in hourly increments.

See: http://ets.aeso.ca/ for publicly available historic metered volumes settlement reports.

Uncertainty The level of uncertainty regarding AESO settlement data is limited due to the number of controls and procedures related to the collection, verification, and settlement of electricity generation data. Meter data collection and settlement are an electronic process defined under the AESO’s Measurement System Standard (2007)2, SCADA Standard (2005)3, and Settlement Process Guide (2010)4 Where information is extracted from the AESO’s Energy Management System (EMS) and entered into a quantification workbook, data points are validated by the offset project quantification team and verified (by third party verifier) to ensure accuracy in translation.

http://www.google.ca/url?q=http://www.aeso.ca/downloads/AESO_Measurement_System_Standard(2).pdf&sa=U&ei=e-elTor7LKqPigKi0JDODQ&ved=0CBIQFjAA&usg=AFQjCNFw3SaEPWAeM021nkaLbcOREmegKA

http://www.google.ca/url?q=http://www.aeso.ca/downloads/AESO_Measurement_System_Standard(2).pdf&sa=U&ei=e-elTor7LKqPigKi0JDODQ&ved=0CBIQFjAA&usg=AFQjCNFw3SaEPWAeM021nkaLbcOREmegKA

http://www.aeso.ca/downloads/SCADA_Standard_Final.pdf

http://www.aeso.ca/downloads/AESO_Settlement_Process_Guide.pdf

http://ets.aeso.ca/



Procurement of Fossil Fuels and Electricity for Facility Operations

Fossil fuels are consumed in operating equipment and the heating the Operations and Maintenance building within the boundary of the Project site. Associated combustion and upstream extraction and processing emissions are accounted for by two parameters: (1) facility operations, (2) fuel extraction and processing.

Provide the Details for any deviations from protocol including the justification

This method complies with the continuous metering described in Table 2.4 of the Protocol and industry standards.

Table 4: Monitoring Plan for Fossil Fuel And Electricity Procurement Source / Sink Identifier or Name P1 Facility Operation

P3 Fuel Extraction and Processing

Data parameter Gasoline, diesel, natural gas consumption, and electricity usage

Estimation, Modeling, Measurement or Calculation approaches

Measurement of Gasoline and Diesel: using procurement receipts which are tabulated using industry standard meters at fuel distribution pump. If the volume on the receipt is unclear, the volume is estimated by dividing the total invoice by the price per litre. If the fuel is not specified, the price per litre is reviewed to determine if it is appropriate for gasoline or diesel, based on pricing information available within several days of the purchase. If the type of fuel cannot be ascertained through this manner, the fuel is assumed to be diesel. Measurement of Natural Gas: utility invoices are tabulated using industry standard meters on site. Measurement of Electricity Usage: All measurements of electricity consumed off the transmission system are submitted to the AESO by the metering services provider. A small amount of power is consumed when the facility is not generating electricity. The substation building and the operations and maintenance building are both distribution power connected. Measurement of this usage is through two meters and data is collected



through utility invoices that are tabulated using industry standard meters on site.

Data Unit L (Diesel and Gasoline), GJ (Natural Gas), MWh (Electricity) Sources / Origin Purchase receipts and utility invoices.

Monitoring Frequency Receipts are collected from point of sale for each transaction

and monthly consumption reports are received from the fleet procurement card services provider. Utility invoices are received on a monthly basis are electricity consumption statements from the AESO.

Description and Justification of Monitoring Method

Gasoline and diesel fuel purchases at regulated fuel pumps are tracked using a fleet fuel procurement card and running monthly reports on the amount of fuel purchased. Fuel purchases are then checked by referencing vendor receipts to ensure accuracy. The utility service provider prepares Natural Gas consumption records, and the invoiced volumes are also recorded in a tracking workbook. After validation by the quantification team (Solas Energy Consulting), values are then transferred to the Quantification Workbook to estimate the quantity of emissions associated with facility operations and upstream fuel extraction and processing. Electricity usage is tracked through two sources, the AESO and distribution connected electricity purchases, which are invoiced monthly. AESO settlement data is the most accurate information related to usage through the HV meter as this information is governed by the Alberta Utility Commission’s Settlement System Code which defines rules for measuring, monitoring, and verification of all settlement data submitted to the AESO. The meter data is validated monthly. Once the metering data has passed validation, the data is aggregated as per the AESO’s measurement point definition and then transferred electronically to the AESO. All meters are governed under the Weights and Measurements Act of Canada (Current, 2011-09-21) with



specific regulations and procedures defined for the calibration and monitoring of such revenue class meters. Electricity usage from the transmission line was determined by referencing AESO Final Pool Statements, which were received by the Project Developer. Electricity consumed is listed under “Energy Charge” in the “Consumption” section of the statement. To confirm, data was pulled from AESO’s online, historic generation database was accessed to retrieve load data, which is available in hourly increments. This data was used to confirm the AESO Pool Statement data. See: http://ets.aeso.ca/ for publicly available historic metered volumes settlement reports.

Uncertainty Uncertainty with fossil fuel procurement records is limited as Meters for gasoline, diesel and natural gas are all governed under the Weights and Measurements Act of Canada (Current, 2011-09-21) with specific regulations and procedures defined for the calibration and monitoring of such revenue class meters. As purchase records are manually entered into a Tracking Workbook and then transferred to the Quantification Workbook, data points are validated (internally) and verified (by third party verifier) to ensure accuracy in translation. The level of uncertainty regarding AESO settlement data is limited due to the number of controls and procedures related to the collection, verification, and settlement of electricity consumption data. The level of uncertainty regarding the Direct Energy data is limited also through controls and procedures related to the collection, verification and billing related to the electricity consumption data.

Provide the Details for any deviations from protocol including the justification

This method complies with the data collection procedures described in Table 2.4 of the Protocol.

http://ets.aeso.ca/



Data Management System

The following sections describe the data management system and data controls for the Project. Each data control point is identified by number in the process flow diagrams included below.

Data Controls for Net Electricity Exports:

Figure 1: Data Process Flow Diagram for Electricity Exports

Table 5: Data Management System for Electricity Exports Data Management Parameter Description of Actions

Source Document AESO Data Historian and Monthly Settlement Statements

System Controls Control Point #1

The facility operations staff reviews data from each individual turbine meter on a regular basis at month end by accessing the “Supervisory Control And Data Acquisition (SCADA)” system. When the SCADA system records errors they are verified and corrected by the facility operator. Information from the SCADA system is compared to a separate meter on the low voltage side



of the substation to ensure it is reasonable and supportable. Any discrepancies are investigated and the third-party meter service provider. The SCADA system is secured and access is limited to Project operational and business management staff with valid security clearance and passwords.

Control Point #2

The secondary quality control function utilizes the meter which is used to report the generation volume to the Alberta Electric System Operator (AESO). This meter is located on the high voltage side of the substation at the point nearest to the transmission interconnection.

Any identified metering issues are brought to the attention of metering services provider. The services provider then investigates and takes the necessary action, including validation and editing where necessary. Once the metering data has passed validation, the data is aggregated as per the AESO’s measurement point definition and then transferred electronically to the AESO once every month, according to the AESO’s settlement process and schedule.

Control Points #3 - 4

Net electricity exports, as stated in Settlement Statements, are checked against the AESO online electricity generation reporting system and entered into the quantification workbook by the project quantification team (Solas Energy Consulting Inc.). These values, and the associated GHG emissions assertion are checked once again by the quantification team as the emission reduction assertion is entered into the Offset Project Report. Both the assertion and the net electricity exports are verified (by third party verifier) to ensure accuracy.

Data Security Data can only be read by a qualified meter reader and meter is sealed.

The SCADA system is secured and access is limited to Project operational and business management staff with valid security clearance and passwords.

Data Integrity Data transfer to AESO is automated. Any identified metering issues are brought to the attention of metering services provider.



The services provider then investigates and takes the necessary action, including validation and editing where necessary. Once the metering data has passed validation, the data is aggregated as per the AESO’s measurement point definition and then transferred electronically to the AESO once every month, according to the AESO’s settlement process and schedule. Meter access is secured, and access is limited to the metering services provider only. Also, revenue class meters are governed by the Weights and Measurements Act of Canada (Current, 2011-09-21). It is a criminal offence when a meter does not measure units of measurement within the limits of error prescribed (Section 24, b).

Data Completeness Errors are investigated through the AESO settlement process.

Data Accuracy The facility operations staff reviews data from each individual turbine meter on a regular basis at month end by accessing the “Supervisory Control And Data Acquisition (SCADA)” system. When the SCADA system records errors they are verified and corrected by the facility operator. Information from the SCADA system is compared to a separate meter on the low voltage side of the substation to ensure it is reasonable and supportable.

Data Validity The meters on the Project site are specified and installed as required under AESO regulations. They were calibrated and sealed by a Measurement Canada approved and accredited company.

Both meters (high voltage and low voltage) meter seals are valid until the expiry 6 years after the seal was applied (2017 Seal).

Certificates of calibration and meter testing are available.

Data Storage/Backup/Retention Data is backed up through the SCADA system, AESO Data Historian and by the metering services provider. Data backup is stored in a secured data room operated by FIRMEX.



Figure 2: Verification, Estimation and Editing Process in Meter Data Settlement5

Data Controls for Fossil Fuel and Electricity Consumption

Figure 3: Fossil Fuel and Electricity Consumption Tracking Process Flow

Table 6: Data Management System for Fossil Fuel and Electricity Consumption

Data Management Parameter Description of Actions

5 AUC Rule 012, Page 115, Performance Standards for Meter Data Managers Operating in the Province of Alberta



Source Document(s) Monthly utility statements (natural gas and distribution utility electricity use), AESO Settlement data (transmission utility electricity use), 3rd Party Fleet Fuel Information System

System Controls Fuel, natural gas, and electricity consumption records are manually entered into a Tracking Workbook by Solas Energy Consulting. Summaries of fuels and electricity consumed for facility operations are then transferred to the Quantification Workbook after and internal validation by the quantification team. These values, and the associated GHG emissions assertion are checked once again by the quantification team as the assertion is entered into the Offset Project Report. Both the assertion and the fuel and electricity consumption data are verified (by third party verifier) to ensure accuracy.

Data Security All metering devices are secured and sealed. Data access to utility and transportation fuel data is secured via password.

Data Integrity Utility Meter readings and calibration of all metering equipment is completed by a qualified metering services provider. Data transfer to information management and data storage systems from metering devices is automated.

Data Completeness Data is reviewed by a data validation team (Solas) and a third- party verifier for completeness.

Data Accuracy Meters are calibrated in accordance with regulatory specifications as defined by the Weights and Measurements Act of Canada, and metering devices are sealed to avoid tampering.

Data Validity Meters for gasoline, diesel, natural gas, and electricity are all governed under the Weights and Measurements Act of Canada (Current, 2011-09-21) with specific regulations and procedures defined for the calibration and monitoring of such revenue class meters. Invoices are electronically generated, limiting human error. Although calibration records are not available on the fuel pumps, and utility meters, it is assumed that the Act governing these revenue class devices will limit any uncertainty with the data.



Data Storage/Backup/Retention Utility statements and fuel consumption data is stored on a secured data room operated by FIRMEX.

Record Keeping

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; • 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 for a period of 7 years.