Bowark Energy OCT 11 2014 App.Pdf

APPLICATION FOR APPROVAL FOR PROPOSED QUEENSTOWN POWER PLANT QUEENSTOWN, ALBERTA (SW 17-19-23-22 W4M)

Submitted to: The Alberta Utilities Commission Calgary, Alberta

Prepared for: BowArk Energy Ltd. Calgary, Alberta

Submitted by: AMEC Environment & Infrastructure Calgary, Alberta

October 2014 CE04460

Alberta Environment and Sustainable Resource Development Application For Approval for Proposed Queenstown Power Plant Queenstown, Alberta (SW 17-19-23-22 W4M) October 2014

TABLE OF CONTENTS PAGE 1.0 INTRODUCTION ...... 1 1.1 Project Summary ...... 1 1.2 Application ...... 1 1.3 Project Ownership and Applicant Information ...... 1 1.4 Affected Parties ...... 3 1.5 Approvals ...... 4 1.5.1 Acts Potentially Affected by this Project and the Responsible Agency ...... 4 1.5.2 Existing Approvals for Facilities Directly Affected by this Project ...... 4 1.5.3 Pending Approvals ...... 4 1.5.4 Application to Alberta Environment and Sustainable Resource Development and List all Other Government Departments and Agencies from which Approval is Required ...... 4 1.6 AESO Requirements ...... 5 1.7 Fuel Gas ...... 5 2.0 PROJECT DESCRIPTION ...... 6 2.1 Project Site and the Regional Setting of the Development ...... 6 2.2 The Number of Generating Units and the Total Capacity (kilovolt ampere (kVA), megavolt ampere (MVA)) for the Project ...... 6 2.3 General Overview of Environmental Impacts (such as Noise, Visual, Emissions, Land Disturbances, Surface Water) ...... 7 2.4 Historical Resources ...... 8 3.0 PUBLIC INVOLVEMENT INFORMATION ...... 10 3.1 Public Notification and Involvement Program ...... 10 3.2 Owners, Occupants and Residents on Lands within the Project Area, as well as Other Interested Parties that you Contacted as Part of your Public Notification and Involvement ...... 12 3.3 Supply a Mailing List of Those Parties Mentioned Above, Complete with Two (2) Sets of Mailing Labels ...... 12 3.4 Identify any Parties who Expressed Concerns about the Project and the Specifics of their Concerns ...... 12 3.5 Summary of Discussions held with Potentially Directly and Adversely Affected Parties ...... 15 3.6 Concerns Raised by Potentially Directly and Adversely Affected Parties and How They Were Dealt With or Will be Dealt With ...... 16 3.7 For Those Potentially and Adversely Affected Parties Identified, a Confirmation of Resolution of the Concerns, if Applicable ...... 16

S:\Project Ce\Ce04460\fin AUC rpt-ce04460-06oct14-mparkhouse.docx Table of Contents Alberta Environment and Sustainable Resource Development Application For Approval for Proposed Queenstown Power Plant Queenstown, Alberta (SW 17-19-23-22 W4M) October 2014

TABLE OF CONTENTS (cont’d) PAGE LIST OF FIGURES

Figure 1-1: Queenstown Generation Plant Site Plan ...... 2 Figure 1-2: Regional Project Map ...... 9

LIST OF TABLES

Table 1-1: Stakeholder Proximity to Project Site ...... 3 Table 1-2: Potentially Affected Acts and Responsible Authorities ...... 4 Table 1-3: Summary of Applications to Government Departments ...... 5 Table 3-1: Stakeholders Sent Information Packages ...... 10 Table 3-2: List of Communications with Stakeholders Requiring Personnel Notification ...... 11 Table 3-3: Vulcan County Questions and Comments ...... 14

LIST OF ATTACHMENTS

Attachment A: Rule 007 Application Information Index Attachment B: Development Permit Attachment C: Notice of Public Hearing to Re-Zone the Project Site Attachment D: Single Line Diagram Attachment E: Area Transmission System Attachment F: Air Quality Assessment Report Attachment G: Participant Involvement Program Attachment H: Historical Resources Act Clearance

1.0 INTRODUCTION 1.1 Project Summary BowArk Energy Ltd. (BowArk) is proposing to construct and operate the Queenstown Power Plant, a simple cycle natural gas-fired peaking power plant, at the intersection of Range Road 225 and Township Road 192 in the County of Vulcan directly adjacent to the existing AltaLink 504s Queenstown Substation. The Project’s generation capacity will be 98 megawatts (MW) and site preparation is scheduled to start in the fall of 2015 with building construction and equipment placement to begin late in 2016. The expected life of the Queenstown Power Plant facility is approximately 35 years. Delays in site preparation or approvals will result in delays in initial operation of this Project.

The generating plant will be comprised of two General Electric aero-derivative LM6000 PF simple cycle gas turbine generating units with a combined maximum rated site capacity of 106 MVA at 0.85 PF. Figure 1-1 shows the location of the Project relative to the existing facilities.

Ducks Unlimited Canada (DUC) is the present landowner of the SW¼ 17-19-22 W4, the site of the proposed Queenstown power plant. BowArk has an “Option to Purchase” agreement with DUC to purchase 34.6 acres of the SW¼ 17-19-22 W4. BowArk will exercise this option to purchase the 34.6 acres of land and will apply for a subdivision from the County of Vulcan.

In support of this, Project BowArk is preparing and submitting an application for an Industrial Approval for this Project to Alberta Energy Regulator (AER) to comply with the requirements in the Environmental Protection and Enhancement Act (EPEA). This application has been prepared in accordance with the Environmental Protection and Enhancement Act – A Guide to Content for Industrial Approval Applications, March 29, 2014 and provides the required environmental and social information.

1.2 Application BowArk hereby applies to the AUC pursuant to Section 11 (Approval of power plant) of the Hydro and Electric Energy Act (RSA 2000) of the Province of Alberta for approval to construct and operate a power plant. The Project is also subject to the Environmental Protection and Enhancement Act.

1.3 Project Ownership and Applicant Information The project is entirely owned by BowArk Energy Ltd.

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Figure 1-1: Queenstown Generation Plant Site Plan

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1.4 Affected Parties The proposed Project is in excess of 2,000 m of the closest resident and is not expected to adversely affect any parties. The Project is located on agricultural land (hay and pastureland) at the intersection of Range Road 225 and Township Road 192 in the County of Vulcan and directly adjacent to the existing AltaLink 504s Queenstown Substation. There are no residents within 2,000 m of the proposed project.

Ducks Unlimited Canada (DUC) is the landowner of the SW¼ 17-19-22 W4, the site of the proposed Queenstown power plant. BowArk has an “Option to Purchase” agreement with DUC to purchase 34.6 acres of the SW¼ 17-19-22 W4. BowArk will be exercising the option to purchase the 34.6 acres of land and will apply to the County for a subdivision.

Siksika Nation is the nearest First Nations and is approximately 10 to 11 km northwest of the Project site and it is not expected that they will be adversely affected. The Alberta Aboriginal Consultation Office advised that consultation with the Siksika Nation is not required. BowArk sent the Siksika First Nation an information package regarding the Queenstown Power Plant and an Alberta Utilities Commission brochure on 29 May 2014.

Table 1-1 below is a list of stakeholders in proximity to the Project site.

Table 1-1: Stakeholder Proximity to Project Site

Legal Description (M, Rge, Twp, Area Land Title # Owner Sec, QS) (ha) Landowners within 800 m radius of proposed power plant facility 131 030 996 007 4-22-19-18-NE, SE, SW 194.1 Ducks Unlimited Canada 031 148 258 001 4-22-19-8-NW 64.7 Christine Joy Egeland Douglas John Bushell 031 148 258 002 4-22-19-8-NE, SE 194.1 Christine Joy Egeland Douglas John Bushell 131 030 996 005 4-22-19-17-SE 64.7 Ducks Unlimited Canada 131 030 996 015 4-22-19-17-NW, NE, SW 184.1 Ducks Unlimited Canada 021 197 185 002 4-22-19-17-SW 2.17 AltaLink Management Ltd 811 179 726 4-22-19-7-NE 65.2 Willard Farms Ltd Landowners between 800 m and 2,000 m radius of proposed power plant facility 811 179 724A 4-22-19-7-SE 64.7 Willard Farms Ltd 170N57 4-22-19-21-NW, NE, SW SE 258.8 Mary Marlene Healy 931 318 172 4-22-19-16-SW 64.7 Douglas John Bushell 811 179 728 4-22-19-7-NW, SW 129.4 Willard Farms Ltd 931 318 170 4-22-19-16-NW 64.7 Christine Joy Egeland 121 138 264 4-22-19-9-NW 64.7 Kodiak Mint Farms Ltd 121 138 271 4-22-19-9-SW 64.7 Emerald Farms Ltd 131 030 996 006 4-22-19-18-NW 64.7 Ducks Unlimited Canada 101 113 860 001 4-22-19-8-SW 64.7 Marsha Kay Willard Landowners between 2,000 m and 3,000 m radius of proposed power plant facility 031 031 131 012 4-22-19-6-SE; NE 64.7 Willard Farms Ltd 041 112 703 4-22-19-16-SE 64.7 Douglas John Bushell County of Vulcan Vulcan County Development Officer Siksika First Nation Richard Right Hand, Consultation Manager

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1.5 Approvals BowArk has prepared and submitted an application for an Industrial Approval for this Project to Alberta Energy Regulator (AER) to comply with the requirements in the Environmental Protection and Enhancement Act (EPEA).

County officials held a public hearing on 3 September 2014 to redesignate the portion of land on which the Queenstown Power Plant will be located as “Rural Industrial – RI”. A Notice of Public Hearing for this hearing was posted as required by the Municipal Government Act. The Project lands were officially rezoned on 6 August 2014 by the County of Vulcan along with an exemption from being required to apply for a development permit. Section 17 of the Municipal Governing Act exempts BowArk from being required to apply for a Development Permit. A subdivision application will be required from the county of Vulcan prior to BowArk exercising its right to purchase the parcel under its option agreement. A copy of the Notice and Rezoning is provided in Attachment C for reference.

Approvals from other agencies are not required.

1.5.1 Acts Potentially Affected by this Project and the Responsible Agency Table 1-2 summarizes the acts potentially affected by the Project and the corresponding responsible authorities.

Table 1-2: Potentially Affected Acts and Responsible Authorities

Responsible Agency Applicable Legislation Application Number Alberta Energy / Alberta Electric System Operator Electric Utilities Act TBD Alberta Environment and Sustainable Resource Environmental Protection and TBD Development Enhancement Act Alberta Utilities Commission Hydro and Electric Energy Act TBD NAV Canada and Transport Canada The Aeronautics Act TBD

1.5.2 Existing Approvals for Facilities Directly Affected by this Project The Project and Project site do not currently have any current approvals, permits or notifications from any regulatory agencies directly related to the Project.

1.5.3 Pending Approvals Pending approvals are listed in Table 1-3.

1.5.4 Application to Alberta Environment and Sustainable Resource Development and List all Other Government Departments and Agencies from which Approval is Required Pending and obtained approvals are listed in Table 1-3.

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Table 1-3: Summary of Applications to Government Departments

Regulatory Approval Required Status Supporting Document Requirement/Regulator Alberta Environment and Approval required under the Application submitted Sustainable Resource Environmental Protection and Pending August 2014 Development Enhancement Act Application submitted Alberta Culture Historical Resources Act Clearance Pending August 2014 Application submitted NAV Canada Land Use Proposal approval Pending August 2014 Approval for Obstruction Marking and Application submitted Transport Canada Lighting under the Canadian Aviation Pending August 2014 Regulations. Application submitted County of Vulcan Development Permit Pending August 2014

1.6 AESO Requirements The Queenstown Power Plan is to be located on LSDs 3 and 4 of Section 17 Township 19 Range 22 West of 4th Meridian. The point of interconnection is the AltaLink 504s substation located adjacent to the proposed power plant within LSD 4 Township 19 Range 22 West of the 4th Meridian. This is in the County of Vulcan approximately 58 km east of High River and 3.3 km north of Highway 542 and 7.5 km southwest of the Hamlet of Queenstown. Power generated by the project will be tied into the provincial electrical grid through the existing AltaLink 504s Queenstown Substation which is located on the western edge of and directly adjacent to the Project site. Figure 1-1 above depicts the location of the connection point.

The approximate latitude and longitude of facility is 50.601993 (50° 36' 7.1748") and -113.027215 (-113° 1' 37.9734").

BowArk is currently an AESO market participant. However, an AESO asset identification code has not yet been assigned to these project assets

1.7 Fuel Gas The maximum predicted natural gas fuel consumption for the power plant is 857 GJ (HHV)/hr during winter operation at rated output. Sales of natural gas will be sourced from TransCanada’s Queenstown 8” NPS lateral located 7.5 km due north of the project site. TransCanada would construct a new meter station adjacent to their lateral and BowArk would construct a buried 8” NPS 8450 kPa Maximum Operation Pressure, 7.5 to 8.0 km line from the new station to the Queenstown site. A minimum gas pressure of 4,700 kPa(g) required by the aero engines may necessitate some fuel gas compression as supply pressure may periodically be as low as 4,000 kPa(g). The environmental effects associated with the natural gas transmission will be limited to land disturbance during construction of the metering station and lateral gas line. BowArk is working with Ducks Unlimited to minimize negative effects to wet lands and river crossings through route selection to avoid these sensitive areas and where avoidance is not possible directional boring or dry season crossings will be utilized to mitigate impact. Air emissions associated with the combustion of the natural gas fuel is detailed in the air emission model attached.

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2.0 PROJECT DESCRIPTION 2.1 Project Site and the Regional Setting of the Development The proposed Project site is located at the intersection of Range Road 225 and Township Road 192 in the County of Vulcan directly adjacent to the existing AltaLink 504s Queenstown Substation at SW 17-19-23-22 W4M. The Project site and property is currently utilized for agricultural (hay and pasture land). The location is adjacent to electrical transmission and oil and gas development (industrial land use) and is south of oil and gas development (industrial land use). Other adjacent properties are comprised of agricultural use (hay, pasture, and cultivated land).

The closest populated area to the proposed project is the Hamlet of Queenstown, located approximately 7 km NE of the proposed Project.

2.2 The Number of Generating Units and the Total Capacity (kilovolt ampere (kVA), megavolt ampere (MVA)) for the Project The generating plant will be comprised of two General Electric aero-derivative LM6000 PF simple cycle gas turbine generating units with a combined maximum rated site capacity of 106 MVA at 0.85 PF. The plant being open cycle requires no water for cooling nor discharges any waste cooling water. Operational Design Life for this type of facility is approximately 35 years beginning in 2016.

Electricity generated by each of the two identical generators will be transmitted from the project’s new McGregor substation to the existing AltaLink 504s Queenstown substation immediately east of the proposed Project site. The resultant new 138 kV transmission circuit will run approximately 70 metres (m) on lands owned by BowArk and AltaLink. Interconnection within AltaLink’s 504s substation will be facilitated by an existing 138 kV bus position which was abandoned as a result of the Southern Transmission Reinforcement system project.

The power plant has a seasonal average heat rate of 9.840 GJ (HHV)/MWhr after station service and transformer losses or an efficiency of 36.6% based on higher heating value of the fuel.

The simple cycle power plant utilizes dry aerial fin fan coolers for lube oil. Generator cooling is by forced air taken from the combustion air filter and directed through the stator and rotor by two axial fans mounted on the rotor shaft and exhausted to atmosphere by vent fans. Vent fans provide cooling to the turbine, generator and auxiliary skid outdoor enclosures.

The proposed Project includes the following key elements: 1. General Electric LM6000 PF gas turbine generator (2); 2. Control, Maintenance and Relay Building; 3. Natural Gas Metering/Compression/Regulation;

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4. 13.8/138 kV 105 MVA Main Stepup Transformer; 5. Station Service Transformer; 6. 13.8 kV Generator Breaker (2); 7. 135 hp Hydronic Heater (GT Inlet Heating); 8. 7.5 km High Pressure Natural Gas Pipeline (submitted under separate application); 9. Interconnecting Piping (submitted under separate application); and 10. Transmission Line (approx. 70 metres).

The power plant will be connected into the Alberta electric system at transmission voltage level. A single-line diagram showing the power plant and the interconnection point to the grid and an area transmission system schematic drawing are provided in Attachments D and E, respectively, for reference.

2.3 General Overview of Environmental Impacts (such as Noise, Visual, Emissions, Land Disturbances, Surface Water) A permit application was prepared for the construction and operation of the Queenstown Power Plant for the Alberta Energy Regulator (AER) under authority of EPEA. This document has been submitted under separate cover and provides a description and assessment of the project’s environmental impacts.

EPEA requires the completion of any environmental impact assessment (EIA) for thermal electrical power generating plants with capacity of 100 megawatts or greater. Since an EIA is not mandatory and it is not expected that the project will result in significant adverse effect, an EIA report was not prepared for this Project.

A noise impact assessment was performed as per Rule 012: Noise Control. The assessment is provided under separate cover and the predicted night-time noise levels do not exceed 40 dBA.

An air quality assessment was performed as part of the AER approval application. Dispersion

modelling was done for NO2 and CO. The modelling results demonstrate that the predicted concentrations of NO2 and CO are in compliance with the Alberta AAQOs for the corresponding averaging periods. Further details are available in the air quality assessment report included Attachment F for reference.

The Project is located within the boundaries of the South Saskatchewan Regional Plan (SSRP). It is located on existing agricultural land (hay and pasture) and will be cleared of vegetation prior to construction. Air emissions are expected from fuel combustion; however, these emissions are in compliance with the Alberta AAQOs for the corresponding averaging periods.

Regional drainage is not affected by the Project. The Project will not significantly alter runoff and there is no watercourse that traverses the Project site.

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A layout diagram of the Project site is provided on Figure 1-1. Figure 1-2 shows the Project location in relation to the surrounding area.

2.4 Historical Resources The historical resources regulator, Alberta Culture (AC), maintains a regularly-updated list of lands with recorded historic resources in the province, based on previous field assessments. A search of this list and of records at AC’s Historic Resources Management Branch Online Web Feature Service was conducted to determine what lands in the vicinity of the Project site have previously been assessed for historic resources. These listings were consulted to determine if the proposed BowArk Queenstown Power Generation Plant site is in conflict with any lands with known Historical Resource Value (HRV). HRV zones show the level of archaeological potential and the level of protection of known archaeological sites.

EdPg-3 was recorded as a prehistoric scatter of cultural material (<10) found as surface material in a previously cultivated field. It was categorized as having low historical resource value and no further work was recommended. EdPg-3 is approximately 1.6 km to the southeast of the proposed Power Generation Plant and will not be disturbed by the Project development.

No paleontological resources have been recorded in the area. No cultural (traditional use), geological, historical, or natural resources protected by the Historical Resources Act have been located in the immediate construction area or the 2 km buffer zone.

There are no HRV zones or known archaeological, historical, or paleontological resources in the proposed Project site. Within the 2 km buffer zone, the only known historical resource (EdPg-3) has been disturbed and has an HRV of zero. The presence of disturbed soils and vegetation on the proposed Project site suggest that if any historic resources are present, their context is now disturbed.

An Application for Historical Resources Act Clearance has been submitted to AC. Based on the lack of archaeological and paleontological potential and existing disturbance by a previous development, the need for the completion of a Historical Resource Impact Assessment is considered and has been recommended as unnecessary. The application has been submitted online to AC in August 2014 (Application #005974550).

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Figure 1-2: Regional Project Map

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3.0 PUBLIC INVOLVEMENT INFORMATION In accordance with the Alberta Utilities Commission (AUC) Rule 007, BowArk Energy Ltd. (BowArk) conducted a Participant Involvement Program. BowArk commenced the program with Public Notification in May 2014 and followed up with Personal Notification.

A Participation Involvement Program Information Package was prepared for the Queenstown Power Plant and McGregor Substation. This package contains a cover letter addressed to each landowner/stakeholder and a brochure providing details of the proposed power plant and substation including the location, on-site equipment, proposed project schedule, BowArk contact details and a copy of the AUC application process. A copy of the Participation Involvement Program Information Package information is provided for reference in Attachment G.

3.1 Public Notification and Involvement Program A Participation Involvement Program Information Package for the Queenstown Power Plant and McGregor Substation was mailed out to the landowners, residences and stakeholders within a 2,000 metre radius of the proposed power plant identified in Table 3-1.

Table 3-1: Stakeholders Sent Information Packages

Landowner Interest Address Comments Ducks Unlimited Canada Titled Landowner 17915 – 118 Avenue 27 May 2014 – Mailed Edmonton, AB T5S 1L6 Information Package Christine Joy Egeland Titled Landowner 220 – 2 St N, PO Box 165 27 May 2014 – Mailed Milo, AB T0L 1L0 Information Package Douglas John Bushell Titled Landowner PO Box 46 27 May 2014 – Mailed Milo, AB T0L 1L0 Information Package - Resident outside the site boundary AltaLink Management Titled Landowner 2611 – 3 Avenue SE 27 May 2014 – Mailed Calgary, AB T2A 7W7 Information Package Willard Farms Ltd. Titled Landowner Box 129 27 May 2014 – Mailed Milo, AB T0L 1L0 Information Package Mary Marlene Healy Titled Landowner Vulcan, AB T0L 2B0 27 May 2014 – Mailed Information Package Kodiak Mint Farms Ltd. Titled Landowner Box 870 27 May 2014 – Mailed Vulcan, AB T0L 2B0 Information Package Emerald Farms Ltd. Titled Landowner Box 870 27 May 2014 – Mailed Vulcan, AB T0L 2B0 Information Package; package OLD -300, 2912 Memorial was returned “not at this Drive SE address”. Mailed out to address Calgary, AB T2A 6R1 in Vulcan Marsha Kay Willard Titled Landowner PO Box 129 27 May 2014 – Mailed Milo, AB T0L 1L0 Information Package - Resident outside the site boundary Gordon Marsh Occupant – leasing PO Box 215 27 May 2014 – Mailed land Arrow wood, AB T0L 0B0 Information Package

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The Siksika First Nation is also interested in the proposed power plant development but not as a direct landowner because the project site is located 10 to 11 km (6 to 7 miles) south of their reserve lands on private agricultural lands and there is no potential adverse effects on navigable waters or traditional activities (e.g., hunting, fishing, gathering). This has been confirmed via recent communications with the Government of Alberta Aboriginal Consultation Office (ACO). However, BowArk mailed an information package to the Siksika First Nation on 29 May 2014.

In compliance with AUC Rule 007, BowArk commenced Personal Notification, after the required minimum 14 days following the mailing of the information packages, with the landowners within an 800 metre radius of the proposed power plant site. There are a total of five title landowners that require Personal Notification; refer to Table 3-2 for a list of landowners and comments.

Table 3-2: List of Communications with Stakeholders Requiring Personnel Notification

Landowner Contact Comments Christine Egeland Christine Egeland Called and spoke to Christine on 13 June 2014. Confirmed that she received the information package and had an opportunity to read through the document and stated all the information was there and didn’t have any questions or concerns. Doug Bushell Doug Bushell Called and spoke to Doug Bushell on 13 June 2014 Confirmed that he received and read through the information package and had a few questions; refer to PP21 for questions and concerns. Willard Farms Marsha Willard - Called and spoke to Marsha Willard on 13 June 2014 owner Confirmed that she received and reviewed the information package; refer to PP21 for questions and concerns. AltaLink Bob MacDonald - Telephone call with Bob MacDonald on 9 July 2014 Management Ltd. Consultant Confirmed that he had received and reviewed the information package. No questions or concerns. Ducks Unlimited Morgan Stromsmoe Met with DUC at the Calgary Office on 28 May 2014 Canada (DUC) See below for further details

Ducks Unlimited Canada (DUC) is the landowner of the SW¼ 17-19-22 W4, the site of the proposed Queenstown power plant. BowArk has an “Option to Purchase” agreement with DUC to purchase 34.5 acres of the SW¼ 17-19-22 W4. BowArk met with DUC last January 2013 to discuss the preliminary plans to develop the power plant. BowArk and DUC representatives met on 28 May 2014 at the Calgary office of DUC where BowArk reviewed the information package with DUC, provided details about the project and responded to concerns and questions raised by DUC.

BowArk has completed the following public consultation steps. 1. Direct face to face contact where possible or contact by telephone was made by BowArk to parties in the immediate area of the project. 2. BowArk completed a mail out of an information package containing details on the proposed development on 27 May 2014 to all stakeholders listed in Table 3-1.

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3. BowArk representatives presented an overview of the proposed project, anticipated maintenance protocols, site plans and surrounding land control to Vulcan County officials. 4. Vulcan County officials have provided information to BowArk regarding the land use and rezoning of the project location, as well as advice on the application process to obtain a development permit. 5. As of the date of the submission of this application, BowArk has not received any Statements of Concern. 6. Vulcan County officials indicated verbally to BowArk that the County did not have any concerns with the proposed Project in their jurisdiction.

3.2 Owners, Occupants and Residents on Lands within the Project Area, as well as Other Interested Parties that you Contacted as Part of your Public Notification and Involvement There are currently no residents within 2 km of the Queenstown Power Plant. However, based on an initial viewing of satellite imagery, it was estimated that there are five (5) residences located between 2,000 m and 3,000 m from the proposed power plant site. BowArk has sent detailed project information packages to the landowner of these properties, as a courtesy. BowArk has also sent the project information packages to the County of Vulcan and the Siksika First Nation both as a courtesy and to establish good relations with these key stakeholders.

As previously indicated, the proposed Queenstown Power Plant is located in the municipal district of Vulcan County. BowArk representatives presented an information package to County officials that included an overview of the project, anticipated maintenance protocols, site plans and surrounding land control.

The use of ESRD’s First Nations Consultation Guidelines is not triggered by the Project. Therefore, First Nations consultation is not required. However, BowArk also mailed an information package to the Siksika First Nation on 29 May 2014. The Siksika reserve is located approximately 10-11 kilometres north of the proposed power plant project.

3.3 Supply a Mailing List of Those Parties Mentioned Above, Complete with Two (2) Sets of Mailing Labels This will be provided directly to the AUC for purposes of confidentiality.

3.4 Identify any Parties who Expressed Concerns about the Project and the Specifics of their Concerns Information and concerns obtained through the public consultation process has been and will continue to be considered during detailed design of the Queenstown Power Plant and the preparation of operational plans. The following concerns and comments have been expressed to BowArk in regard to the project.

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1. Doug Bushell – Mr. Bushell owns land within 800 metres of the site boundary; his residence is located outside the of 2,000 metre radius. During a telephone conversation on 13 June 2014, Mr. Bushell asked the following questions: a) Will the proposed power plant cause an increase in traffic on the roads in the area? BowArk advised that the only increase in traffic in the area will be during the site preparation and construction of the power plant. The plant will be fully automated with minimal full time employees on-site, no notable increase in traffic once the plant is operating. b) What direction is the proposed pipeline to the plant coming from? BowArk stated that it is not confirmed, but anticipated that the pipeline will be coming from the north. c) What will the site/plant look like? BowArk responded that the plant will look similar to the power plant on the front of the information brochure he received. 2. Marsha Willard, owner of Willard Farms – owns land within 800 metres and 2,000 metres and has a residence located outside of the 2,000 metre site boundary. During a telephone conversation on 13 June 2014, Ms. Willard expressed the following concerns: a) Concerned about the visual of a power plant in the open country, she said that maybe planting trees around the power plant would lessen the visual impact the power plant would have on the surrounding country scenery. BowArk will undertake a review of the visual impact of the power plant to determine if any mitigation measures can effectively be employed, such as a tree hedge row. b) Concerns about the noise levels produced from the power plant. The Noise Impact Assessment had not been completed at the time of this call and it was advised that we would contact her once the assessment was completed. On 29 July 2014, BowArk contacted Ms. Willard to discuss the results of the Noise Impact Assessment. The Noise Impact Assessment concluded that the power plant sound levels at several receptor points located at 1,500 metres were compliant with Alberta Utilities Commission (AUC). The noise levels at the 1,500 metre receptors were 30 – 35 dBA and can be compared to a soft whisper at 1.5 m, as referenced in the Noise Impact Assessment report. According to the findings of the Noise Impact Assessment, the noise levels at Ms. Willard’s residence, located more than 2,000 metres from the site, will be inaudible. On 12 August 2014, BowArk posted the Noise Report to BowArk’s web page for public review, as per our information circular.

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3. Ducks Unlimited Canada (DUC) – On 28 May 2014, BowArk attended a consultation meeting held at the Calgary office of DUC. Pat Bowes and Shelley Sammartino from BowArk met with Morgan Stromsmoe, Herman Rea and Ashley Rawluk, representatives from Ducks Unlimited Canada. BowArk reviewed the information package with DUC and provided updated details about the project responding to questions and the concern DUC had. a) Concerned about the impact the project will have on the ephemeral slough located on the NE¼ of the project site. BowArk advised it will minimize the impact to the seasonal basin with sufficient setbacks and/or by building erosion/silt/runoff prevention barriers during construction. 4. Siksika First Nation – On 16 June 2014, Cheryl Black from the Siksika First Nation emailed BowArk and requested the dates BowArk would be available to meet with them. BowArk replied via email on 18 June 2014 with several dates that BowArk representatives were available for a meeting. As of 12 August 2014, there has not been any response from the Siksika First Nation. 5. Vulcan County – The County is interested in receiving information about industrial developments within its municipal jurisdiction. County officials have provided information to BowArk regarding the land use and rezoning of the project location, as well as advice on the application process to obtain a development permit. Vulcan County officials indicated to BowArk that there were not any concerns with the power plant in their jurisdiction.

Table 3-3 below outlines the specific questions posed by the County regarding the project and BowArk’s response.

Table 3-3: Vulcan County Questions and Comments

Question/Comments Response What is the length of the gas line connecting to the The proposed Queenstown Power Plant requires a plant? pipeline to bring natural gas to the gas turbine generators. It is probable that BowArk will construct and operate a pipeline approximately 7 km in length from the Project site connecting to the existing TransCanada Line which lies north of the facility. What noise levels will be produced by the plant? A Noise Impact Assessment has been completed, a copy of which will be provided to the County. What studies will be done as the project moves In addition to the Noise Impact Assessment, studies will forward? be conducted for air emissions, heritage review, field and desktop studies of: wildlife species, vegetation and water systems with review of the plant’s impacts and mitigation measures. Referred to the road approach on the site plan map and BowArk will contact the Director of Operations prior to suggested that BowArk contact the Director of finalizing the road approach and necessary road Operations with Vulcan County (Nels Petersen) agreements. regarding the placement of the approach, any weight restrictions and road agreements.

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Question/Comments Response Will BowArk be having an Open House for the BowArk will not be holding an Open House as the landowners in the area? number of landowners within the project area is small. BowArk will be consulting with the landowners within the 800 metre radius by telephone or a face to face meeting if requested. Information packages have been mailed to all landowners and stakeholders within a 2,000 metre radius. County Officials indicated that BowArk is required to BowArk has submitted the rezoning application and submit an application to rezone the current land use to anticipates a response in early September 2014. Rural Industrial prior to submitting an application for a development permit or application to subdivide the portion of the project site lands from the current land title.

3.5 Summary of Discussions held with Potentially Directly and Adversely Affected Parties Telephone conversations were held with landowners within the 800 metre radius of the site boundary. The landowners asked questions regarding increase in traffic on the roads in the area and what the plant will look like. BowArk advised the only notable increase in traffic will be during the construction phase of the project and that the plant will be remotely operated with minimal full time employees on-site; there will only be a limited increase in traffic once the plant is operating. BowArk provided a photo of the power plant on the information brochure; this photo is a sample of what the Queenstown power plant will look like.

Another landowner expressed their concern regarding noise produced from the plant and the overall visual of the power plant in a rural setting. The results of the Noise Impact Assessment were provided verbally, and BowArk indicated that a copy of the report is located at www.bowark.com. BowArk will undertake a review of the visual impact of the power plant to determine if any mitigation measures are required.

The current landowner of the proposed Project site and surrounding land is concerned about the impact the project will have on the ephemeral slough located on the NE¼ of the project site. BowArk advised it will minimize the impact to the seasonal basin with sufficient setbacks and/or by building erosion/silt/runoff prevention barriers during construction.

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3.6 Concerns Raised by Potentially Directly and Adversely Affected Parties and How They Were Dealt With or Will be Dealt With DUC is concerned about the impact the project will have on the ephemeral slough located on the NE¼ of the project site. At a meeting with DUC, BowArk advised it will minimize the impact to the seasonal basin with sufficient setbacks and/or by building erosion/silt/runoff prevention barriers during construction.

3.7 For Those Potentially and Adversely Affected Parties Identified, a Confirmation of Resolution of the Concerns, if Applicable Not applicable.

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Attachment A

Rule 007 Application Information Index

Application Component Section Part 1: Applicant Information Applicant Type Primary Applicant Company Name BowArk Energy Ltd. Contact Name Pat Bowes Telephone / Fax (403)-264-2259 Email Address [email protected] Mailing Address Suite 4301 Devon Tower 400 - 3rd Ave SW Calgary AB, T2P 4H2 Part 2: Project Overview 1 Application Description 1.1 2 Are there other Commission applications directly related to this 1.2 application: Part 3: Application Types 1 Identify what this application is for. 1.1 & 1.2 2 Is the application for a power plant less than 1 MW? 1.1 3 Power plant applications one megawatt (MW) or greater 3.1 Application requirements 3.2 Information Requirements PP1 Identify the sections of the Hydro and Electric Energy Act under 1.2 which the application is made. PP2 Identify any other acts (e.g., Environmental Protection and 1.2 & 1.5 Enhancement Act that may affect the project. PP3 State the approvals that are being applied for from the Commission, 1.2 and provide a draft of the approval being requested.

PP4 Provide a list of existing approvals for facilities directly affected by 1.5 this project, if any. PP5 Provide details and outcome of consultation with local jurisdictions 1.4, 3.1 & 3.4 (e.g., municipal districts, counties). PP6 Provide a list of parties that may be affected by the project, confirm 1.4 (Table 1-1), 3.1 & 3.4 that these parties have no concerns regarding the application, and indicate which other agreements are necessary to carry out the project.

PP7 For wind power plants, provide a copy of approval from Transport Not applicable Canada for any structures 20 metres or taller and an evaluation from NAV Canada.

PP8 Provide a copy of the approval from Alberta Transportation if a wind Not applicable power plant that is within 300 metres of a numbered highway is being applied for.

PP9 Confirm that an application to AESRD has been made, if applicable, 1.1 & 1.5 and list all other government departments and agencies from which approval is required.

For all power plant applications, an AESRD wildlife biologist must be included on the referral list, unless the project is located within an urban area. The Commission requires a sign-off from AESRD prior to processing any new wind power applications. Application Component Section PP10 With respect to new facilities or alterations, that may have 2.4 & Attachment H archaeological or historical impacts, confirm that a Historical Resources Act clearance has been obtained or is being applied for. If a historical or archaeological impact assessment is required, briefly describe any historical or archaeological sites close to the power plant site. Please ensure that any summary provided protects the confidential location of any historical resources.

PP11 Provide the ISO assigned asset identification code, if available 1.6 PP12 Provide the legal description of the proposed power plant site (legal 1.1 & 1.6 subdivision [LSD], Section, Township, Range, Meridian) and connection point, if applicable. PP13 For wind power plant applications, provide the longitude and latitude Not applicable coordinates for the centre of each structure supporting a wind- powered generator. If, after approval is granted, the location of any supporting structure has to be relocated more than 50 metres from the coordinates stated in the application, the power plant proponent must reapply to the Commission for approval to relocate the structure prior to construction. For movement less than 50 metres, the applicant is not required to reapply unless there is an adverse impact on the permissible sound level or wildlife setback distances.

PP14 Describe the number of generating units and the total capacity 1.1 & 2.2 (kilovolt-ampere [kVA], or megavolt-ampere [MVA]) for the project.

PP15 Describe the existing environmental and land use conditions on the 2.3 & EPEA Application project site, and discuss potential siting and land use issues. Also, describe the regional setting of the development including regional land use plans in force (e.g., the Lower Athabasca Regional Plan). If applicable, include maps showing important environmental features and sensitive areas on or near the project site.

PP16 At a level of detail commensurate with the size and type of potential 2.3 & EPEA Application impact(s) of the project, describe how the project is predicted to adversely affect the environment (such as soils, terrain, vegetation, wetlands, wildlife and wildlife habitat, fish and fish habitat, groundwater, surface water, air quality, and land use), and visual aesthetics. Describe how the environmental and visual aesthetic effects of the project will be mitigated and any monitoring proposed to evaluate the efficacy of the mitigation.

PP17 If the project site occurs within the plan boundaries of a regional land use plan in force: i. Confirm that the proposed project is being developed in 2.3 accordance with the applicable regional land use plan. ii. Confirm if the proposed project is in a conservation area or 2.3 provincial recreation area established in the applicable regional land use plan. Provide submissions describing how the activity may be considered incidental to a previously approved activity. Application Component Section iii. Indicate what, if any, management frameworks in place under the 2.3 applicable regional land use plan are applicable to the project, the reason why any management frameworks are not applicable to the project and summarize discussions held with AESRD and any other government department required to be consulted under the management frameworks regarding the project and its impacts in terms of the management frameworks. Include details on any actions or mitigation measures recommended as a result of the discussions and describe how these actions or mitigation measures will be incorporated into the project.

PP18 Describe the participant involvement information. (See Appendix A – 3.0, 3.1 & Attachment G Participant involvement program requirements). PP19 List all occupants, residents and landowners on lands within 2,000 1.4, 3.1, 3.2, 3.4 & 3.5 metres of the project area, as well as other interested persons that were consulted as part of the participant involvement program. If there are populated areas just outside the 2,000 metre limit, applicants should consider including those areas in the participant involvement program.

PP20 Supply a list of mailing addresses, with corresponding land locations 3.3 and two sets of printed mailing labels of those parties mentioned in PP19, above.

PP21 Identify any persons who expressed concerns about the project and 3.4 & 3.5 the specifics of their concerns.

PP22 Summarize discussions held with potentially directly and adversely 3.4 & 3.5 affected persons. PP23 If potentially directly and adversely affected persons raised any 3.4 & 3.5 concerns, describe how they were dealt with or are being dealt with.

PP24 For those potentially directly and adversely affected persons 3.4 & 3.5 identified above, include a confirmation of resolution of the concerns, if applicable. PP25 If the power plant is to be located within an oil and gas facility, Not applicable confirm the power plant will comply with the standards outlined in Section 8.090 of the Oil and Gas Conservation Rules.

PP26 Provide a noise impact assessment, in accordance with the current Submitted under separate AUC Rule 012. cover PP27 For an application where no changes to the major components of the 2.2 & EPEA Application power generating equipment are contemplated after filing of the application, provide details of the power generating equipment and associated facilities, such as make, model and nominal capacity.

PP28 For an application where vendors to supply the major components of 2.2 & EPEA Application the power generating equipment have not been selected, provide the nominal capacity of the applied-for power plant and the design and maximum operating parameters, and characteristics specified for the power generating equipment and associated facilities.

PP29 Present the estimated power plant heat rates, efficiency of the power 2.2 & EPEA Application plant and details of the cooling system for the power plant. Application Component Section PP30 State the fuel requirements of the power plant, including type, 1.7 source, method of handling, transportation and environmental effects. PP31 Provide a legible plant site drawing showing all major equipment 1.1 components. PP32 Provide a legible map showing the power plant site boundaries and 2.4 land ownership, including any residences and dwellings within 2,000 metres of the boundaries, as well as any additional energy-related facilities within the project area.

PP33 Provide a legible map of the project area suitable for use in a public 1.1 & 2.4 notice. PP34 Supply the expected in-service dates, and describe ramifications if 1.1 the approval date cannot be met. PP35 Indicate the plant’s emission rates, in kilograms per megawatt-hour 2.3 & Attachment F (kg/MWh) of nitrogen oxides (NOx), sulphur dioxide (SO2), and primary particulate matter, and state whether the emissions will comply with the current Alberta Source Emission Standards and any other emission rate standards or guidelines that are applicable to the proposed project.

PP36 State whether the proposed plant will comply with the Alberta 2.3 & Attachment F Ambient Air Quality Objectives and Guidelines Summary and any other standards or guidelines that are applicable to the proposed project for ground-level concentrations of pollutants. PP37 Provide the environmental impact assessment as an appendix to the Not applicable application, if one has been conducted.

The applicant must obtain approval from AESRD for thermal power plant facilities greater than one megawatt in total capacity at one site. An environmental impact assessment is mandatory for thermal power plant facilities that use non-gaseous fuel and are greater than 100 megawatts in total capacity; an environmental impact assessment may be required for other power plant facilities regardless of total capacity. When an environmental impact assessment is not mandatory, AESRD will determine if it is necessary, based on the specific nature of the project. The applicant should consult with the Commission and AESRD in the initial stages of preparing its application to determine the level of detail required.

PP38 If the power plant is to be connected to the transmission system of Attachment D the Alberta Interconnected Electric System, irrespective of voltage level, provide the following information:  An electrical single-line diagram obtained from the ISO or sanctioned by the ISO showing the transmission development plan for the interconnection.  A map with one or more conceptual layouts showing possible routes and general land locations for facilities that would be used to interconnect the power plant to the Alberta Interconnected Electric System. PP39 If the power plant is to be connected at distribution voltage level to Not applicable the Alberta Interconnected Electric System (generally less than 69 kV), the applicant must provide a statement from the distribution facility owner indicating that it is willing to connect the generating facilities. Application Component Section PP40 For a municipality or a subsidiary of a municipality to hold an interest Not applicable in a generating unit, documentation confirming compliance with Section 95 of the Electric Utilities Act is required.

PP41 For a wind power application, provide legible maps and/or air photo Not applicable mosaics upon which the proposed collector power line route or routes have been imposed and showing the residences, landowner names, and major land use and resource features (e.g., vegetation, topography, soil type, existing land use, existing rights-of-way, and superficial and mineable resources).

3.3 Power plant application 1) Provide the names of all other companies having ownership in the 1.3 (Sole owner) project, details of their incorporation, and the share in the project that each would have. (Note: Do not answer this question if you are the sole owner of the project). 2) What is the energy source of the power plant? 1.7 3) Select type of generator used at the power plant. 1.1 & 2.2 4) Have you conducted a participant involvement program? If you 3.0 & Attachment D answer “No” you must provide reasons. If you answer “Yes”, ensure that you provide details about your program in the Participant Involvement Program attachment. 5) Are there outstanding public or industry objections and/or concerns? 3.4

6) Have you completed a noise impact assessment, as required by 2.3, 3.4 & 3.5 Rule 012: Noise Control? 7) Provide the AESO Pool Participant Asset ID Number(s). 1.6 8) Is there an application for connection accompanying this power plant Not applicable application? If Yes: You must include an Interconnection application type together with the Power Plant application type in Schedule 1. If No: You must then answer Question 8a: “At what voltage level is the connection” and select either Distribution level or Transmission level.

8a) At what level is the connection? 2.2 (Transmission Voltage)

9) Provide the legal description of the proposed plant site (and latitude 1.6 and longitude for each wind generating unit, if applicable). Note: For wind power plant applications, provide the longitude and latitude coordinates for the centre of each structure supporting a wind- powered generator. For all other power plant types, provide the longitude and latitude coordinates of the powerhouse.

3.4 Power Plant Application Attachments Application Attachment A Development Permit Attachment B Participant Involvement Program Attachment D Mailing Labels Attachment E Noise Impact Assessment Submitted under separate cover Alberta Transportation Approval (For wind power plant applications) Not applicable

NAV Canada Approval (For wind power plant applications) Not applicable Transport Canada Approval (For wind power plant applications) Not applicable

Project Area Map Figure 1-2 Application Component Section Plant Site Boundary Map Figure 1-1 Plant Site Drawing Figure 1-1 Environmental Impact Assessment Not applicable If the power plant is to be connected at transmission voltage level (generally 69 kV or greater), the following information must be provided in the attachments indicated below:

Electric Single-Line Diagrams Attachment D Project Area Map Figure 1-2 Connection Agreement Not applicable 3.5 Wind Power Plant Applications Not applicable 3.6 Ammendments to Approved Wind Power Plant Not applicable

Attachment B

Development Permit

From: Anne Erickson To: [email protected] Subject: Vulcan County Development Date: September-10-14 4:22:48 PM

Hi Shelley, I tried to give you a call back from your last voicemail but I got your voicemail and the message system said temporarily unavailable. So, I thought I would shoot you an email.

Your rezoning application was approved. On behalf of Vulcan County I would like to thank you for your application.

Section 17 in the MGA exempts you from being required to apply for a Development Permit. It also exempts you from Subdividing. So, at this time, no other permits are required from Vulcan County. With that being said, once BowArks decides to purchase the property from Ducks, BowArk will have to subdivide in order to purchase the rezoned parcel.

Vulcan County would appreciate if BowArk would keep us “in the loop” though and offer the County regular updates as to your progress on the project.

Clear as mud?

Please give me a call if you would like to discuss this further.

Thank you.

Sincerely,

Anne Erickson Development Officer l Projects Coordinator

Vulcan County 102 Centre Street l Box 180 l Vulcan l T0L2B0 d: 403-485-3132 t: 403-485-2241 f: 403-485-2920 e: [email protected]

Disclaimer: This message is intended for the use of the individual or entity to which it is addressed and may contain information that is privileged, confidential and exempt from disclosure.

Attachment C

Notice of Public Hearing to Re-Zone the Project Site

Attachment D

Conceptual Single-Line Diagram of the Queenstown Power Plant and Substation

7.4 Single Line Drawing –Queenstown 504S Substation- Proposed Development

138kV Bus 475L – 138kV to 161L – 138kV to McGregor Lake Vulcan 255S Plant 200S

Spare

853L – 138kV to West Brooks 28S

Legend Proposed Note: Circuit Breaker Development This single line diagram provides an illustration of the Shunt Reactor functional arrangement that would meet the need of the proposed project. Although the TFO is required to Queenstown substation 504S - Ganged Air- Switch maintain the specified functionality, the exact routing (Motor- operated) and configuration of the project proposed by the TFO Proposed Development in its facility application may vary slightly from this Ganged Air- Switch (Manual Operation) configuration based on more detailed engineering, routing and siting information obtained by the TFO in 1336-SLD-200S-1 preparation of its Facility Application.

File No. 1336 R0 AESO Functional Specification Page 17 of 23 7.5 Single Line Drawing – Proposed McGregor Lake 200S

475L 138kV circuit to Queenstown 504S AltaLink Point of connection

Queenstown Generation Plant T1 Transformer 138 kV- 13.8kV 105 MVA

13.8 kV Bus

Station Service Transformer 13.8 kV-480V

Station Loads Generator G1 Generator G2 45 MW 45 MW 13.8kV 13.8kV

Legend: Note: Information shown in this single line diagram was provided by the McGregor Lake 200S Substation- Customer. It provides an illustration of a functional arrangement Transformer Disconnect Switch that would meet the need of the proposed project. It is conceptual Proposed Development in nature. Final station configuration may vary slightly from this SLD at the completion of detailed engineering. Generator Circuit Breaker 1336-SLD-200S-1

File No. 1336 R0 AESO Functional Specification Page 18 of 23 P1336 Connection Proposal

EL-1 Drawing No Underground Cable Circuit Breaker Note Transformer Air Break Switch March 5, 2013 # LEGEND Drawing Title Substation 200S-Conceptual SLD 200S-Conceptual Substation Station Service Station transformer Station Station Load Max 1 MW El Panel 13.8 kV 120/208 V 1 Phase 105 MVA Z=12% X/R =25 5% +/- taps, 5 NLTC: 200ST1 Client Project 2500 A 31.5 kA BIL kV 170 CVT1 13.85 kV, 5000A, 3PH, 3W 31.5 kA SC RMS Queenstown Generating Plant 200S G BowArk Energy Ltd. BowArk Energy 52 Bus 758 138kV G2 138 kV 13.8 kV Queenstown Generation Plant Revenue metering (Rev Class CT) Sync (Relay Class CT) DT2 13.8 kV 13.8 5000 A CB112500 A 31.5 kA BIL kV 170 CB12 DT1 145 kV A 1200 G G1 52 SAT1 MOV 93kV 120 kV NOT FOR CONSTRUCTION Trip Simultaneous Reviewed By D. Brankovich, P.Eng. 267 MCM ACSR (Partridge), 1c/phase, 500 m long 267 MCM D.Brankovich, P.Eng. 52 Queenstown 504S Bus 333 138kV This is a conceptual design. vary may design Engineering actual The 1. A new bay to be created for this project 2. Optional alternate 120/208 V power supply, if available NOTES Feb 23, 2013 0 Rev Date Description Designed By

R[x] Public Transmission Project Delivery 18 R1-2012-02-10

Attachment E

Area Transmission System Schematic Diagram

Functional Specification Revision History

Revision Description of Revision By Date

R0B0 For Comments Henry Ng 2013-7-9

R0B1 For Comments Henry Ng 2013-7-26

R0B2 For Comments Henry Ng 2013-9-6

R0B3 For Comments Henry Ng 2013-11-4

R0 For Issuance Henry Ng 2013-11-12

File No.1336 R0 AESO Functional Specification Page 2 of 23

TABLE OF CONTENTS

1 PURPOSE ...... 4 2 INTERPRETATION AND VARIANCES ...... 4 3 PROJECT OVERVIEW ...... 4 4 FORECAST OF FUTURE DEVELOPMENT IN THE PROJECT AREA 5 5 SCOPE OF WORK ...... 5 5.1 General ...... 5 5.2 Compliance with AESO Authoritative Documents ...... 6 5.3 Modeling Data Requirements ...... 6 5.4 Substation Equipment Specifications ...... 6 5.5 Specific Scope of Work for the Legal Owner of the Transmission Facility ...... 7 5.6 Market Participant Scope of Work ...... 9 6 TRANSMISSION SYSTEM OPERATING CHARACTERISTICS ..... 10 6.1 Short Circuit Current Levels ...... 10 6.2 Voltage Levels ...... 12 6.3 Insulation Levels ...... 12 6.4 Specific Project Operational or Transmission Constraints ...... 13 6.5 Remedial Action Schemes ...... 13 6.6 Generator Synchronization ...... 13 6.7 Anti-Islanding ...... 13 7 APPENDICES ...... 14 7.1 Existing Area Transmission System ...... 14 7.2 Area Transmission System at completion of SATR Blackie Area Re- configuration Project and Proposed Connection of Queenstown Generation Plant15 7.3 Single Line Drawing – Queenstown 504S Substation at completion of SATR Blackie Area Re-configuration Project ...... 16 7.4 Single Line Drawing –Queenstown 504S Substation- Proposed Development17 7.5 Single Line Drawing – Proposed McGregor Lake 200S ...... 18 7.6 Energy Data Requirements ...... 19 7.6.1 SCADA Point Requirements – Queenstown 504S Substation ...... 19 7.6.2 SCADA Point Requirements – McGregor Lake 200S ...... 20 7.5.2 SCADA Data Requirements – ...... 21

File No.1336 R0 AESO Functional Specification Page 3 of 23

1 PURPOSE (1) The purpose of this document (the “Functional Specification”) is to set out the technical specifications and requirements and approved variances issued by the AESO to the legal owner of the transmission facility, AltaLink Management Ltd. (“ATCO”), and the market participant, BowArk Energy Ltd. (“BowArk”), related to the design, construction, development and commissioning of certain new or modified facilities (the “project”) that have been proposed for or are related to a physical facilities connection with the interconnected electric system (the "Purpose"). (2) This Functional Specification is issued for the Purpose only, and the legal owner of the transmission facility and the market participant must comply with the Functional Specification provisions. (3) The ISO is not responsible for any facilities designed by or for any third party, or installed on a third party’s behalf, to accomplish the connection of the project facilities. (4) This Functional Specification includes: (i) certain specific engineering, technical and functional requirements for the project; (ii) the requirements to comply with ISO rules, including OPPs, reliability standards, technical standards, and ISO Tariff provisions, (the “Authoritative Documents”); (iii) the electrical system environment in which the connecting facilities must be designed and operate; and (iv) any approved variances from requirements set out in any applicable AESO Authoritative Documents.

2 INTERPRETATION AND VARIANCES (1) Subject to subsection (2), any revision or variance to any of the Functional Specification provisions by the legal owner of the transmission facility or the market participant is prohibited. (2) The legal owner of the transmission facility or the market participant may make application in writing to the AESO requesting a variance to this Functional Specification, and the AESO may in writing approve of the variance after the AESO has completed an analysis of the implications to the interconnected electric system with respect to the requested variance. (3) Words or phrases appearing in bold have the meanings set out in the Authoritative Document Consolidated Glossary.

3 PROJECT OVERVIEW BowArk Energy Ltd. (“BowArk”) proposed to construct the Queenstown Generation Plant (“the Project”) as a new point of supply (POS). The plant consists of two 45 MW gas fired generators with a total generation of 90 MW. The plant will be designed to allow base load and peaking operation in addition to ancillary services. The Maximum Authorized Real Power (“MARP”) for each generator is 45 MW. Maximum Capability (“MC”) at the point of connection is 87 MW. BowArk is requesting a Supply Transmission Service (“STS”) capacity of 90 MW and a Demand Transmission Service (“DTS”) of 1.2 MW at the completion of this project.

File No.1336 R0 AESO Functional Specification Page 4 of 23

This proposed transmission development includes the following: • Addition of one (1) 138 kV circuit breaker and associated disconnect switches at Queenstown 504S substation. • Construct one circuit of approximately 100m from Queenstown 504S to connect the market participant’s McGregor Lake 200S substation. This project is dependent on and shall be in service only after the completion of SATR Blackie Area 138 kV Re-configuration Project (Project number 1354).

The requested in-service date for the project is September 30, 2015.

4 FORECAST OF FUTURE DEVELOPMENT IN THE PROJECT AREA Refer to the AESO Long Term Transmission Plan filed June 2012 on AESO’s website for future development in the project area.

5 SCOPE OF WORK 5.1 General (1) The legal owner of the transmission facility and the market participant must complete all engineering, design, land or land-use acquisition, siting, public consultation, applicable regulatory approvals and permits, material procurement, construction, commissioning, and associated permitting requirements for the project facilities. (2) The legal owner of the transmission facility and the market participant must coordinate with each other as required on all project facility design details, including protection and control, grounding, insulation, point of connection, and site layout. (3) The legal owner of the transmission facility and the market participant must develop joint operating procedures (JOP) and any connection agreements as required such that all connecting transmission facilities will operate safely and reliably. (4) The legal owner of the transmission facility and the market participant must deliver to the AESO all final design and as-built project facility information and records in the format and content required by the AESO, to enable the AESO to update and maintain its technical records and system models. (5) The legal owner of the transmission facility and the market participant must submit the project information and records referred to in subsection (4) above, under the professional stamp and signature of a registered professional engineer in Alberta who assumes responsibility for the preparation and accuracy of the content of the information and records. (6) The legal owner of the transmission facility and the market participant must ensure that all project facilities have been inspected by professional and certified inspectors in accordance with industry standards and practices, so that the project facilities are declared to be: (a) safe for operation prior to energization; and (b) in compliance with this Functional Specification, and any Authoritative Documents for which the project must comply (7) No project facilities are to be energized until an energization authorization has been issued by the AESO in accordance with the ISO rules.

File No.1336 R0 AESO Functional Specification Page 5 of 23

5.2 Compliance with AESO Authoritative Documents The legal owner of the transmission facility and the market participant must comply with the Authoritative Documents provisions which are applicable to the project, including those provisions contained in: • AESO Operating Policies and Procedures • Independent System Operator (ISO) Rules including but not limited to:

o ISO Rules, Section 502.2, Bulk Transmission Line Technical Requirements (effective January 1, 2012);

o ISO Rules, Section 502.3, Interconnected Electric System Protection Requirements (effective December 31, 2012);

o ISO Rules, Section 502.4, Automated Dispatch and Messaging System and Voice Communication Systems Requirements (effective January 8, 2013);

o ISO Rules, Section 502.8, SCADA Technical and Operating Requirements (effective February 28, 2013);

o ISO Rules, Section 505.3, Coordinating Synchronization, commissioning, WECC Testing and Ancillary Services Testing (effective December 31, 2012);

o ISO Rules, Section 505.4, Coordinating Operational Testing (effective December 31, 2012); and

o ISO Rules, 9.1, Transmission. • AESO Alberta Reliability Standards • AESO Measurement System Standard Rev. 1 (dated September 18, 2007)1; • AESO Generation and Load Interconnection Standard (dated September 19, 2006)1;

5.3 Modeling Data Requirements All modeling data is to be provided per the following information document: Information Document 2010-001R Transmission Modeling Data Requirements (dated February 15, 2010).

5.4 Substation Equipment Specifications (1) All transmission equipment must meet the following minimum specifications: • Temperature rating of -50ºC for all outdoor equipment. • Equipment maximum and minimum continuous voltage ratings as indicated in Table 1. • Minimum continuous equipment current ratings as indicated in Table 2. • Equipment maximum fault level – 31.5 kA for 138 kV.

Table 1: Nominal & Maximum Continuous Equipment Operating Voltages (kV)

1 The AESO considers this standard to remain in effect notwithstanding the statement in clause 1.5 in the standard. Efforts to revise the standard are currently underway through an industry work group.

File No.1336 R0 AESO Functional Specification Page 6 of 23

Area 138kV Nominal 138 Maximum 150

Table 2: Minimum Continuous Equipment Current Ratings (A)

Component 138 kV Main Bus1 1200 Cross Bus2 600 Feeder3 or line terminal4 600

1. Main bus includes all sections of ring bus scheme and single bus of simple bus scheme. 2. Cross bus includes diameter sections of breaker and a half or breaker and third schemes. 3. Feeder includes all equipment from the connection at the low voltage bus to the riser pole. 4. Line terminal includes all equipment and conductor from the transmission line to the line breakers.

5.5 Specific Scope of Work for the Legal Owner of the Transmission Facility 5.5.1 General Requirements • Coordinate with the market participant to develop necessary connection agreements and JOPs. • Ensure project safety is appropriately managed from design through construction. • Complete insulation coordination studies and coordinate with the market participant as required to establish appropriate insulation levels. • Undertake all required grounding studies, testing, and mitigation to ensure the transmission facilities are safe.

(1) Queenstown 504S Substation – See Appendices 7.3 & 7.4 Augmentation of Queenstown 504S substation: . Install one (1) 138 kV circuit breaker with associated disconnect switches. . Terminate 475L to McGregor Lake 200S. Protection and Control . Install breaker failure protection functionality for the new 138 kV circuit breaker. . Install synch check relay on the new 138 kV breaker. . Initiate transfer trip signal to trip the generators simultaneously at Queenstown Generating Plant when the new 138 kV breaker is tripped by the substation bus, breaker failure and backup protection. . Trip the new 138 kV breaker upon receipt of transfer trip signal from McGregor Lake 200S. . Install all other required protection equipment for the safe and reliable operation of Queenstown 504S substation.

File No.1336 R0 AESO Functional Specification Page 7 of 23

. Coordinate with the market participant to determine interface requirements for protection and control.

. Modify existing 161L line protection equipment at both Queenstown 504S and Vulcan 255S substations as required, to reduce total fault clearance time to less than 10 cycles.

. Complete system protection coordination studies and coordinate with the market participant to establish settings appropriate for the facility additions and ATS operations.

. Install protection and control equipment as required to implement the generator out of phase closing protection scheme as described in section 6.6. Telecommunication . Modify/upgrade existing tele-communication equipment as required and appropriate communication interface at Queenstown 504S such that voice, SCADA, OPX, and tele-protection requirements are met. . Establish a mutually acceptable communication scheme with the market participant as required to manage the protection, control and data acquisition traffic between the legal owner of the transmission facility and the market participant’s facility. . Install additional telecommunication equipment as required to provide protection signaling between Queenstown 504S and Vulcan 255S in order to reduce the total fault clearance time on 161L by one of the following options: o Option 1 - Install additional microwave dish at Queenstown 504S, Vulcan 255S and Buffalo Hill repeater station. Install microwave telecommunication terminal equipment at both Queenstown 504S and Vulcan 255S substations. o Option 2 – Confirm OPGW is available between Queenstown 504S and Vulcan 255S at the completion of Blackie Area 138kV System Re- configuration project (AESO project number 1038). Install fibre optics telecommunication terminal equipment at both Queenstown 504S and Vulcan 255S substations. Note: The legal owner of the transmission facility to provide cost estimate of both options in their Proposal to Provide Service and to recommend the use of either microwave or OPGW as the medium of tele-communication between Queenstown 504S and Vulcan 255S substations.

SCADA . Establish communications interface point with the connecting the market participant facilities such that voice and SCADA data can be transmitted back to the AESO’s SCC. . Control Center data mapping and verification of SCADA information for the proposed transmission facility modifications and additions and any associated changes required at other area substations. A complete listing of energy data requirements can be found in Appendix 7.6 of this document.

File No.1336 R0 AESO Functional Specification Page 8 of 23

(2) 138 kV transmission line 475L Construct one circuit of approximately 100m from existing Queenstown 504S substation to the new McGregor Lake 200S substation. The new circuit shall be designated as 475L. Minimum summer capacity of the circuit shall be 105 MVA at 138 kV. (4) Miscellaneous • All site preparation, fencing, foundations, grounding, support structures, termination structures, cabling, bus work, station service, control building, protection, controls, SCADA equipment, etc. as required to complete the additions and/or modifications outlined above.

5.6 Market Participant Scope of Work (1) General Requirements . Coordinate with the legal owner of the transmission facility to develop necessary connection agreements and JOPs. . Unless otherwise noted, the anticipated operating ranges are provided in Section 5.4 entitled “Substation Equipment Specification” and Section 6.0 entitled “Transmission System Operating Characteristics”. . Complete all required grounding studies, testing, and mitigation to ensure facility and personnel safety. . Ensure project safety is appropriately managed through all stages of the project life cycle. (2) McGregor Lake 200S (Proposed, constructed and operated by the market participant) – See Appendix 7.5 Construct a new McGregor Lake 200S. Major equipment . One (1) 138 kV motorized disconnect switch. . One (1) 138kV/13.8 kV 105 MVA generator step-up transformer. . One (1) 13.8 kV/480V station service transformer. . Three (3) 13.8 kV circuit breakers with associated disconnect switches. . Two (2) 45 MW generators. . Coordinate with the legal owner of the transmission facility to terminate 475L at McGregor Lake 200S. Protection and Control . Coordinate with the legal owner of the transmission facility on insulation coordination, protection coordination, supervisory control and data acquisition facilities. . Coordinate with the legal owner of the transmission facility to ensure all the HV equipment can be operated safely with any necessary and appropriate interlocking requirements incorporated in the station design.

File No.1336 R0 AESO Functional Specification Page 9 of 23

. Coordinate with the legal owner of the transmission facility to install any interface as required for protection and control. . Install all protection and control (“P&C”) equipment required for the market participant’s facility in accordance with ISO Rule 502.3. . Two independent high-speed protection systems shall be installed. . Initiate transfer trip signal to trip the new 138 kV breaker at Queenstown 504S when the transformer protection at McGregor Lake 200S has operated. . Trip all the generator breakers upon receipt of transfer trip signal from Queenstown 504S. . Install interlocks on the 138 kV motorized disconnect switch as required to prevent inadvertent out-of-phase closing of the generators. . The underfrequency and overfrequency protection settings of the generators must be set in accordance with table 3-1 “Frequency Ranges” in the AESO’s Generation and Load Interconnection Standard. SCADA - Refer to Appendix 7.6 . Install SCADA system to provide status, analog, control and alarm data for the new facilities. The data is to be communicated to the AESO Control Centre for real time operations. Telecommunication . Install communication facilities to transmit the control and data acquisition traffic related to the new facility additions at the market participant’s facility to the AESO Control Centre. . Establish a mutually acceptable communication scheme with the legal owner of the transmission facility as required to manage the protection, control and data acquisition traffic between the legal owner of the transmission facility and the market participant’s facility. Revenue Metering . Provide description of the measurement point location for the point of delivery/point of supply, and the acceptable installation options for revenue metering in order to report on the measurement point. . All new Point of Supply (POS) and Point of Delivery (POD) metering points shall be established in accordance with the AESO’s Measurement System Standard as described in Section 5.2.

6 TRANSMISSION SYSTEM OPERATING CHARACTERISTICS The legal owner of the transmission facility and the market participant must ensure all facilities are capable of operating in the following electrical environment. 6.1 Short Circuit Current Levels (1) The short circuit current levels set out in Tables 3 and 4 have been developed by the AESO based on information provided by the legal owners of the transmission facility, any connecting generating units, and adjacent operating areas. Available fault current levels will continue to increase as generation, transmission, and system inter-ties are added to the interconnected electric system. The legal owner of the transmission facility and

File No.1336 R0 AESO Functional Specification Page 10 of 23

market participant must continue to review the fault levels and their equipment ratings for adequacy. (2) Any future equipment upgrades or protection system setting changes required due to increasing fault levels are the responsibility of the legal owner of the transmission facility or the market participant, as applicable. (3) The following assumptions were incorporated into the AESO short circuit current models: (i) All expected Alberta generation is dispatched. (ii) All transmission elements are in service. (iii) The proposed project facility is connected as per this document.

(iv) Vbase = Vbus, MVAbase = 100

Table 3: Estimated Maximum Short Circuit Current Levels (2015) Prior to Connection

Pre- Positive Sequence Zero Sequence Substation Base 3-Φ 1-Φ Fault Thevenin Source Thevenin Source Name and Voltage Fault Fault Voltage Impedance p.u. Impedance p.u. Number (kV) (kA) (kA) (pu) (R1+jX1) (R0+jX0)

Queenstown 138 1.02 2.86 0.05697+j0.13852 1.8 0.12409 + j0.40382 504S Vulcan 255S 138 1.01 1.8 0.06167 + j0.14664 1.8 0.12893 + 0.43517

West Brooks 28S 138 1.03 13.9 0.00499 + j0.03048 15.6 0.00121 + 0.02048

Bassano 435S 138 1.02 3.3 0.04620 + j0.11859 2.1 0.09538 + j0.33149

Table 4: Estimated Maximum Future (2015) Short Circuit Current Levels After Connection

McGregor Lake 138 1.03 4.9 0.02003 + j0.08443 4.8 0.00894 + j0.09439 200S Queenstown 138 1.02 5.3 0.02004 + j0.08438 5.0 0.00926 + j0.09536 504S Vulcan 255S 138 1.01 3.7 0.03661 + j0.10958 2.7 0.05390 + j0.24244

West Brooks 28S 138 1.03 14.5 0.00477 + j0.029 14.7 0.00284 + 0.02769

Bassano 435S 138 1.02 3.5 0.04259 + j0.11141 2.2 0.08941 + j0.31447

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Table 5: Estimated Maximum Future (2022) Short Circuit Current Levels

McGregor Lake 138 1.03 4.7 0.02208 + j0.08775 4.7 0.00886 + j0.09441 200S Queenstown 138 1.03 4.8 0.02209 + j0.08206 4.7 0.00918 + j0.09538 504S

Vulcan 255S 138 1.02 3.6 0.03830 + j0.1114 2.7 0.05315 + j0.24281

West Brooks 28S 138 1.03 15.3 0.00464 + j0.02767 15.4 0.00282 + j0.02751 Bassano 435S 138 1.02 3.6 0.04322 + j0.11075 2.3 0.08939 + j0.31435

6.2 Voltage Levels Table 6 provides the planned operating voltage range in the area of the proposed facility.

Table 6: Planned Operating Range Substation Name and Nominal Minimum Normal Normal Maximum Number (kV) Limit (kV) Operating Operating Limit (kV) Minimum (kV) Maximum (kV)

Queenstown 504S 138 124 135 145 150 McGregor Lake 200S 138 124 135 145 150

Notes: 1. The Normal Operating Minimum and Normal Operating Maximum are generally associated with Category A events and system normal. 2. The Minimum Limit and Maximum Limit are generally associated with Category B, C, and D events and system abnormal. 3. The facilities must be capable of continuous operation at voltages up to and including the Maximum Limit.

6.3 Insulation Levels (1) Table 7 provides the minimum required basic insulation levels for the transmission system. Station equipment with lower insulation levels may be used provided that protection and coordination can be maintained with judicious insulation design and use of appropriate surge arresting equipment. (2) For 25 kV circuit breakers where there is a grounded wye transformer and surge arrestors are installed a basic insulation level of 125 kV is acceptable.

Table 7: Basic Insulation Levels (kV)

Nominal Voltage Classification (kV rms) 138 Station Post Insulators and Airbreaks 550 Circuit Breakers 650

File No.1336 R0 AESO Functional Specification Page 12 of 23

Current and Potential Transformers 650 Transformer Windings (Protected by Surge Arresters) 550

6.4 Specific Project Operational or Transmission Constraints Refer to the operating conditions and constraints outlined in the ISO Rule 302.1, formerly the Operating Policy and Procedure (OPP) 501.

6.5 Generator Synchronization The connecting generating unit will be synchronized across the 13.8 kV breakers. The generating unit must be equipped with full synchronizing equipment, capable of assuming full control of the governor system and automatic voltage regulator during the synchronizing process. 6.6 Generator out of phase closing protection To prevent out of phase closing onto the Queenstown generators, synch check relay and associated line voltage transformers, shall be available at the following line terminals: 1. Queenstown 504S substation a. 138 kV line 853L to West brooks 28S substation. b. 138 kV line 161L to Vulcan 255S substation. 2. West Brooks 28S substation a. 138 kV line 853L to Queenstown 504S substation 3. Vulcan 255S substation a. 138 kV line 161L to Queenstown 504S substation. b. 138 kV line 180L to Fort Macleod 15S substation. 4. Fort Macleod 15S substation a. 138 kV line 180L to Vulcan 255S substation.

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7 APPENDICES 7.1 Existing Area Transmission System

Cavalier To Janet Strathmore 733L Power 151S 74S 765L Namaka STN 428S 886L

733 L Hussar To 431S Langdon Carseland 102S Cogen

Carseland 850L 525S Gleichen To Janet 179S 74S

Bassano 435S 876 L

851L

To High 853 AL 753L 924L River 927L 65S 852L 853L Blackie Queenstown To West 253S 504S Brooks 28S L To Milo

161 356S To Vulcan Legend 255S Notes This schematic drawing is intended to illustrate the electrical Area Transmission System– Existing 138 kV Line Generator interconnection of the area transmission system. It is not to Existing 2012 scale, nor does it depict the exact Existing 240 kV Line line routes or substation locations. 1336-SYS-01

File No. 1336 R0 AESO Functional Specification Page 14 of 23

7.2 Area Transmission System at completion of SATR Blackie Area Re-configuration Project and Proposed Connection of Queenstown Generation Plant

Cavalier To Janet Strathmore 733L Power 151S 74S 765L Namaka STN 428S 886L

733 L Hussar To 431S Langdon Carseland 102S Cogen

Carseland 850L 525S Gleichen To 179S Okotoks 678S Bassano 435S 876 L

851L

To High 924L 853 AL 753L River 927L 65S 853L Blackie Queenstown To West 253S 504S Brooks 28S L To Milo

161 356S Proposed To Development Vulcan Legend 255S Notes This schematic drawing is intended to illustrate the electrical Area Transmission System– Existing 138 kV Line Generator interconnection of the area transmission system. It is not to 2015 scale, nor does it depict the exact Existing 240 kV Line line routes or substation locations. 1336-SYS-02

File No. 1336 R0 AESO Functional Specification Page 15 of 23

7.3 Single Line Drawing – Queenstown 504S Substation at completion of SATR Blackie Area Re-configuration Project

138kV Bus 161L – 138kV to Vulcan 255S

Spare

853L – 138kV to West Brooks 28S

Legend

Circuit Breaker

Shunt Reactor Queenstown Substation 504S - Ganged Air- Switch (Motor- operated) Post SATR Development

Ganged Air- Switch (Manual Operation) 1336-SLD-504S-1

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7.4 Single Line Drawing –Queenstown 504S Substation- Proposed Development

138kV Bus 475L – 138kV to 161L – 138kV to McGregor Lake Vulcan 255S Plant 200S

Spare

853L – 138kV to West Brooks 28S

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7.5 Single Line Drawing – Proposed McGregor Lake 200S

475L 138kV circuit to Queenstown 504S AltaLink Point of connection

Queenstown Generation Plant T1 Transformer 138 kV- 13.8kV 105 MVA

13.8 kV Bus

Station Service Transformer 13.8 kV-480V

Station Loads Generator G1 Generator G2 45 MW 45 MW 13.8kV 13.8kV

File No. 1336 R0 AESO Functional Specification Page 18 of 23

7.6 Energy Data Requirements 7.6.1 SCADA POINT REQUIREMENTS – QUEENSTOWN 504S SUBSTATION

DATA TO AESO 11 Status

22 MW/MVar Analogs

33 Voltage (kV) Analog

44 LTC Tap Position (Analog)

55 LTC Auto/Manual Status

66 RAS Armed and Operated Status

77 Total RAS MW available and MW armed

88 Communication Failure Alarm

99 RTU Failure Alarm 109 MVAR Analog 138kV Bus 119 VAR Compensating Device 22 475L – 138kV to Status 161L – 138kV to McGregor Lake 9 12 PSS and AVR Status Vulcan 255S 11 200S 139 Frequency

149 Generator Mode (voltage control or constant pf)

159 Generator Regulating Control Status (Enabled/Disabled) Spare Generator MW setpoint from the 169 generator’s control system (Analog)

179 High and Low Regulation Range Limit in MW (Analog)

20 Voltage Regulation System Setpoint (Analog) 853L – 138kV to DATA FROM AESO West Brooks 28S

51 A status indication that AESO has control over the resource 52 MW setpoint to the Plant (Analog)

Legend Proposed

Circuit Breaker Development

Shunt Reactor Queenstown substation 504S - Ganged Air- Switch (Motor- operated) Proposed Development

Ganged Air- Switch (Manual Operation) 1336-SLD-200S-1

File No. 1336 R0 AESO Functional Specification Page 19 of 23

7.6.2 SCADA POINT REQUIREMENTS – MCGREGOR LAKE 200S

DATA TO AESO 11 Status 475L 138kV 22 MW/MVar Analogs circuit to Queenstown 33 Voltage (kV) Analog 504S 44 LTC Tap Position (Analog)

55 LTC Auto/Manual Status

66 RAS Armed and Operated Status

77 Total RAS MW available and MW armed 11 88 Communication Failure Alarm T1 9 9 RTU Failure Alarm Transformer 109 MVAR Analog 138 kV- 22 13.8kV 119 VAR Compensating Device 105 MVA Status 129 PSS and AVR Status 33 13.8 kV Bus 139 Frequency

149 Generator Mode (voltage control or constant pf) 11 11 11 159 Generator Regulating Control Status (Enabled/Disabled)

Generator MW setpoint from the 169 generator’s control system (Analog) Station Service 179 High and Low Regulation Range Limit in MW (Analog) 22 Transformer 13.8 kV-480V 189 Ambient temperature in degrees Celsius 22 33 22 33 139 129 139 129 Voltage Regulation System Setpoint 20 189 149 189 149 (Analog) Station Loads 20 159 20 159 179 169 179 169 DATA FROM AESO Generator G1 Generator G2 51 A status indication that AESO has 45 MW 45 MW control over the resource 13.8kV 13.8kV 52 MW setpoint to the Plant (Analog) 88 66 * 51* 99 77 * 52* Legend: * If Applicable Queenstown Generation Station Transformer Disconnect Switch 200S -Proposed Development Notes: 1. This single line diagram is conceptual in Generator Circuit Breaker nature and subject to change. 1336-SLD-200S-1

File No. 1336 R0 AESO Functional Specification Page 20 of 23

7.5.2 SCADA DATA REQUIREMENTS – Update Facility/ Device Element Indication Rate/ Notes Location Mode Queenstown Breaker CB1 Status On Event 138kV Circuit Breaker associated with 475L to 200S 504S

138kV Line 475L MW 15s Outgoing MW from this substation to 200S on 475L 138kV Line 475L MVAr 15s Outgoing MVAr from this substation to 200S on 475L

Queenstown Breaker CB1 Status On Event 13.8kV Circuit Breaker associated with G1 Generation 200S Breaker CB2 Status On Event 13.8kV Circuit Breaker associated with G2 13.8kV Circuit Breaker associated with Station Service Breaker CB3 Status On Event Transformer

MOS MOS1 Status On Event 138kV MOS associated with 475L to 504S

Transformer T1 MW 15s MW reading at high side, towards T1 Transformer T1 MVAr 15s MVAr reading at high side, towards T1

MW reading at high side, towards Station Service Station Service 13.8kV/480V MW 15s Transformer MVAr reading at high side, towards Station Service Station Service 13.8kV/480V MVAr 15s Transformer

Generator G1 MW 15s Gross MW Generator G1 MVAr 15s Gross MVAr Generator G1 kV 15s Generator voltage at the generator terminal Generator G1 PSS On Event Generator Power System Stabilizer Enabled/Disabled Status Generator G1 AVR On Event Generator Automatic Voltage Regulator Automatic/Manual Status Generator G1 Status On Event Generator Mode (Voltage Control/Constant power factor)

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Generator G1 Status On Event Generator regulating control disable/enable status (if participating in regulating reserves market) Generator G1 MW 2s Generator set point in MW from the generator control system (if participating in regulating reserves market) Generator G1 MW 10s Generator unit high limit of regulating range (if participating in regulating reserves market) Generator G1 MW 10s Generator unit low limit of regulating range (if participating in regulating reserves market) Generator G1 AVR 15s Voltage Regulation System Setpoint (Analog) Generator G1 DEGC 15s Ambient temperature of the unit in degrees Celsius Generator G1 HZ 15s Unit frequency as measured at the stator winding terminal Generator G2 MW 15s Gross MW Generator G2 MVAr 15s Gross MVAr Generator G2 kV 15s Generator voltage at the generator terminal Generator G2 PSS On Event Generator Power System Stabilizer Enabled/Disabled Status Generator G2 AVR On Event Generator Automatic Voltage Regulator Automatic/Manual Status Generator G2 Status On Event Generator Mode (Voltage Control/Constant power factor) Generator G2 Status On Event Generator regulating control disable/enable status (if participating in regulating reserves market) Generator G2 MW 2s Generator set point in MW from the generator control system (if participating in regulating reserves market) Generator G2 MW 10s Generator unit high limit of regulating range (if participating in regulating reserves market) Generator G2 MW 10s Generator unit low limit of regulating range (if participating in regulating reserves market) Generator G2 AVR 15s Voltage Regulation System Setpoint (Analog) Generator G2 DEGC 15s Ambient temperature of the unit in degrees Celsius Generator G2 HZ 15s Unit frequency as measured at the stator winding terminal

Communication Ganged alarm indicating that 1 or more devices supplying Communications Alarm On Event Failure data is in alarm This is contingent upon the communication method being Communications RTU Failure Alarm On Event an RTU

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Status indication that AESO has control over the resource From AESO Plant CTG/STG Status On Event (if participating in regulating reserves market) AESO MW Setpoint to the Plant (if participating in Plant CTG/STG MW 4s regulating reserves market)

Note 1. MW and MVAr SCADA data shall be gathered independently of the revenue metering data 2. An external GPS based signal shall be utilized to provide 1ms time stamped event accuracy

File No. 1336 R0 AESO Functional Specification Page 23 of 23 7.2 Area Transmission System at completion of SATR Blackie Area Re-configuration Project and Proposed Connection of Queenstown Generation Plant

Cavalier To Janet Strathmore 733L Power 151S 74S 765L Namaka STN 428S 886L

733L Hussar To 431S Langdon Carseland 102S Cogen

Carseland 850L 525S Gleichen To 179S Okotoks 678S Bassano 435S 876L

851L

To High 924L 853AL 753L River 927L 65S 853L Blackie Queenstown To West 253S 504S Brooks 28S To Milo

161L 356S Proposed To Development Vulcan Legend 255S Notes This schematic drawing is intended to illustrate the electrical Area Transmission System– Existing 138 kV Line Generator interconnection of the area transmission system. It is not to 2015 scale, nor does it depict the exact Existing 240 kV Line line routes or substation locations. 1336-SYS-02

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Attachment F

Air Quality Assessment Report

BowArk Queenstown Generation Plant Project Air Quality Assessment

Submitted to: BowArk Energy Ltd. Calgary, Alberta

Submitted by: AMEC Environment & Infrastructure Calgary, Alberta

August 2014

CE04460

BowArk Energy Ltd. Queenstown Power Generation Plant August, 2014

TABLE OF CONTENTS

PAGE

1.0 INTRODUCTION ...... 1

2.0 ASSESSMENT APPROACH ...... 2 2.1 Assessment Cases ...... 2 2.2 Air Quality Modelling Domain and Study Area ...... 2 2.3 Temporal Boundaries ...... 4 2.4 Terrain ...... 4 2.5 Receptors ...... 4 2.6 Background Concentrations ...... 4 2.7 Air Modelling Approach ...... 7 2.7.1 CALPUFF Dispersion Model ...... 7 2.7.2 CALMET Meteorology...... 9 2.8 Air Quality and Emissions Criteria ...... 18 2.8.1 Ambient Air Quality ...... 18

3.0 PROJECT-ONLY CASES ...... 18 3.1 Introduction ...... 18 3.2 Project Emissions ...... 18 3.3 Project-only Case Predictions ...... 19

3.3.1 NO2 Predictions ...... 19 3.3.2 CO Predictions...... 20

4.0 CUMULATIVE CASE ...... 20 4.1 Introduction ...... 20 4.2 Cumulative Case Predictions ...... 21

4.2.1 NO2 Predictions ...... 21 4.2.2 CO Predictions...... 22

5.0 CONCLUSIONS ...... 22

6.0 REFERENCES ...... 23 6.1 Literature Cited ...... 23 6.2 Internet Sites and Personal Communications ...... 23

Table of Contents BowArk Energy Ltd. Queenstown Power Generation Plant August, 2014

TABLE OF CONTENTS (cont) PAGE

LIST OF TABLES

Table 1 Background Concentrations (μg/m³) for the Assessment ...... 5 Table 2 Major Features of the CALPUFF Model ...... 8 Table 3 Temperature (◦C) Derived from CALMET for the Project (2002 to 2006) ...... 10 Table 4 CALMET Derived PG Stability Class Frequency at the Project (2002- 2006) ...... 12 Table 5 Predicted Seasonal Mixing Height (m) Derived for the Project ...... 14 Table 6 Buildings Dimensions for the Project ...... 17 Table 7 Alberta Ambient Air Quality Objectives ...... 18 Table 8 Project Emissions ...... 19 Table 9 Project-only Case NO2 Predictions ...... 20 Table 10 Project Case CO Predictions ...... 20 Table 11 Background Facility Emissions ...... 21 Table 12 Cumulative Case NO2 Predictions ...... 22 Table 13 Cumulative Case CO Predictions ...... 22

LIST OF FIGURES

Figure 1 Air Quality Study Area ...... 3 Figure 2 Gridded Receptors ...... 6 Figure 3 CALMET-Derived Windrose for the Project Area (2002 to 2006) ...... 10 Figure 4 CALMET-Derived Temperature for the Project Area (2002 to 2006) ...... 11 Figure 5 Frequency of Predicted PG Stability Class at the Project (2002- 2006) ...... 13 Figure 6 CALMET-Derived Mixing Heights for the Project Area (2002 to 2006) ...... 15 Figure 7 CALMET Predicted Mixing Height for Different Seasons and Times of Day at Project (2002 to 2006) ...... 16

LIST OF APPENDICES

Appendix A Figures

Table of Contents BowArk Energy Ltd. Queenstown Power Generation Plant Queenstown, Alberta August, 2014

1.0 INTRODUCTION BowArk Energy Ltd. (BowArk) is proposing to build the Queenstown Power Plant (the Project), a simple cycle natural gas-fired peaking power plant. The Project is to be located on the SW1/4 of Section 17, Township 19, Range 22, West of the 4 Meridian.This is approximately 58 km East of High River and 7.5 km southwest of the hamlet of Queenstown. BowArk plans to construct and operate the Project on a site adjacent to the existing Altalink 504s Queenstown Substation at the intersection of Range Road 225 and Township Road 192 in the County of Vulcan. The project’s generation capacity shall be 98 megawatts (MW). The in-service date is currently Late 2016. The expected life of the natural gas facility is approximately 35 years. This power plant will require an approval from Environment & Sustainable Resource Development (ESRD) under the Environmental Protection and Enhancement Act (EPEA). This report provides an air quality assessment of the Project in support of an approval application to ESRD. The air quality assessment considers the potential effects of Project emissions in relation to the Alberta Ambient Air Quality Objectives (AAQOs) (ESRD , 2013a). The air quality impacts associated with the proposed plant will be evaluated for the following compounds:

• NOX and nitrogen dioxide (NO2 ); and • carbon monoxide (CO).

Measured background concentrations from representative air quality monitoring stations in the region were added to the predicted concentrations to assess cumulative effects, as recommended in the Air Quality Model Guidelines (AQMG) (ESRD , 2013a).

This assessment included all industrial emission sources within a minimum of 5 km from the Project. Therefore, both Project-only and Cumulative scenarios were evaluated for the maximum operation phase of the Project. This air quality assessment focuses on determining compliance with existing Alberta objectives and guidelines.

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2.0 ASSESSMENT APPROACH

2.1 Assessment Cases Air quality effects associated with two assessment cases are considered: the Project-only Case and the Cumulative Case. These two assessment cases permit the examination of air quality effects associated with the Project in combination with the existing industrial emission sources within 5 km area of the plant and proposed Project emission sources. The emission sources from the Project are evaluated at their maximum operating conditions, and therefore, their highest operating emissions levels. This results in a conservative overall assessment of the potential impacts of the Project. • The Project-only Case represents the air quality conditions expected to result from the Project alone at the maximum operating conditions. • The Cumulative Case: The Cumulative Case reflects the sum of the Project Case and the background facilities within 5 km area of the Project. 2.2 Air Quality Modelling Domain and Study Area The boundaries of the study area were selected to cover the geographic extent in which the potential air quality effects of the Project are expected to be measurable. The AQMG recommends that the assessment area be sufficiently large to depict concentrations amounting to 10% or more of the regulatory objectives. Based on this information, the air quality assessment considers three regions for the air quality predictions. They are as follows:

• The modelling domain defines a region over which air quality predictions are performed. Emission sources located within the modelling domain are quantified and used in the dispersion modelling. • The study area defines a region over which the graphic results of the air quality modelling are presented. The study area is defined as a 20 by 20 km area centered on the Project. This area is large enough to capture the air quality effects associated with the Project. • The Project developed area is the area occupied by the plant within the Project boundary. The Alberta AAQOs are applicable outside the Project developed area.

Figure 1 shows the study areas and the Project developed area used in the air quality assessment.

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Figure 1 Air Quality Study Area

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2.3 Temporal Boundaries

Temporal boundaries for the air quality assessment include several time averaging periods. Ground-level concentrations of air contaminants are estimated and presented for one-hour, 8- hour, and annual averaging periods, depending on the contaminant. These averaging periods were selected to correspond with the relevant regulatory ambient air quality criteria.

2.4 Terrain Terrain elevations were derived from the Canadian Digital Elevation Model (CDED, 2014) with a horizontal resolution of approximately 30 m. The terrain is relatively flat in the study area with elevations ranging from about 860 metres above sea level (masl) in the river valley to approximately 1150 masl in the west area. The McGregor Lake and Little Bow River system is located at the east of the study area. The terrain of the study area is shown in Figure 1. 2.5 Receptors Ground-level concentrations were modelled at selected locations within the modelling domain. The selection of these locations (referred to as receptors) was based on the AQMG. Receptors were placed as follows: • 20-m receptor spacing along the property boundary, • 50-m receptor spacing within 0.5 km from the source, • 250-m receptor spacing within 2 km from the sources of interest, • 500-m spacing within 5 km from the sources of interest, • 1000-m spacing beyond 5 km.

This receptor scheme is presented in Figure 2.

2.6 Background Concentrations In accordance with the AQMG, appropriate contaminant concentrations due to natural sources, nearby sources, and unidentified, possibly distant sources are to be used as background to be added to predicted values. There are one existing industrial sources within 5 km of the plant.

To determine an appropriate background value for modeling results, a review of available

ambient monitoring data was conducted. The representative station with NO2 data is the Breton station operated by the Fort Air Partnership (FAP). The Breton station is 300 km away from the plant, but in an area similar in use and proximity to development as the Project, so representative of Project conditions. The latest three years of complete data (2011 to 2013) from this station were obtained from the Clean Air Strategic Alliance website. The CO monitoring data are available from the Crescent Heights monitoring station. The three years of data (2011 to 2013) from this station were collected from Crescent Heights monitoring station. A summary of the data is given in Table 1.

The Alberta AQMG recommends using the 90th percentile of the monitored values as the background for 1-hour and 8-hour concentrations and the maximum monitored values as the background for annual concentrations. These values are shown in Table 1.

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Table 1 Background Concentrations (μg/m³) for the Assessment

Data Averaging Max 90%ile 3 Contaminant Station Availability Period (μg/m ) (ug/m3) 1-hour 79.6 15.0

NO2 Breton 94% Annual 7.39 7.22 Crescent 1-hour 4350 229 CO Heights 94% 8-hour 2476 245

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Figure 2 Gridded Receptors

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2.7 Air Modelling Approach The air quality assessment requires dispersion modelling to predict ground-level concentrations. The air dispersion model selection was based on numerous criteria, including: • the capability of the model to evaluate the various regional source types (e.g., point, area and volume sources); • the capability of the model to predict the necessary pollutant concentrations; • the technical basis of the dispersion model that must be scientifically sound and must incorporate the most current understanding of the dispersion of airborne contaminants; • the assumptions and algorithms used in the model must be clearly set out and have undergone rigorous independent scrutiny by peers in the technical community; • the predictions made by the model are consistent with local observations; and • the acceptability of the model by the AQMG as suitable for use.

Based on the above criteria, the CALPUFF dispersion model (Version 6.42) was selected for this assessment. 2.7.1 CALPUFF Dispersion Model CALPUFF is a multi-layer, multi-species non-steady-state puff dispersion model that can simulate the effects of time and space-varying meteorological conditions on pollutant transport, transformation and removal. CALPUFF contains algorithms for near-source effects such as building downwash, transitional plume rise, partial plume penetration, as well as longer-range effects such as chemical transformation, and pollutant removal (wet scavenging and dry deposition) (Scire. 2000). CALPUFF is currently considered the state-of-the-art in regulatory modeling and represents a major improvement over previous models for the following reasons: • it is applicable over spatial scales from a few meters to hundreds of kilometres, allowing the modeling of both local and regional air impacts; • it incorporates the BPIP-PRIME downwash algorithm found in other advanced models used to predict building downwash in the vicinity of emission sources; • it can model wet and dry removal processes (deposition); • it has algorithms to simulate SO2 and NOX chemistry for secondary particulate formation and for predicting acidification; • it models dispersion in three dimensions, allowing for more realistic plume movement; • it allows winds to vary in space in response to channelling and blocking by terrain, removing a constraint in older models; • it can model dispersion in calm winds, another major shortcoming of older models; and • it has been widely used for research and has thus undergone extensive peer review.

Major features of the CALPUFF model are provided in Table 2.

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Table 2 Major Features of the CALPUFF Model

Source Types • Point sources (constant or variable emissions) • Line sources (constant emissions) • Volume sources (constant or variable emissions) • Area sources (constant or variable emissions) Non-steady State Emissions and Meteorological Conditions (if CALMET is used) • Gridded 3D fields of meteorological variables (winds, temperature) • Spatially variable fields of mixing height, friction velocity, convective velocity scale, Monin- Obukhov length, precipitation rate • Vertically and horizontally varying turbulence and dispersion rates • Time-independent source and emissions data

Dispersion Coefficient (σy, σz) Options

• Direct measurements of σv and σw

• Estimated values of σv and σw based on similarity theory • Micrometeorology dispersion coefficients (rural areas) • Pasquill-Gifford (PG) dispersion coefficients (rural areas) • McElroy-Pooler (MP) dispersion coefficients (urban areas) Vertical Wind Shear • Puff splitting • Differential advection and dispersion Plume Rise • Partial penetration • Buoyant and momentum rise • Stack tip effects • Vertical wind shear Dry Deposition • Gases and particulate matter • Three options: • Full treatment of space and time variations of deposition with a resistance model • User-specified diurnal cycles for each pollutant • No dry deposition Chemical Transformation Options

• RIVID/ARM3 scheme chemical mechanism for SO2, SO4, NOx, HNO3, and NO3 • Specified hourly time-series of ozone concentrations of transformation rates Wet Removal • Scavenging coefficient approach • Removal rate a function of precipitation intensity and precipitation type Graphical User Interface • Click and point model set-up and data input • Enhanced error checking of model inputs

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All the modelling options used in the model are default CALPUFF model options as recommended by AQMG. 2.7.2 CALMET Meteorology Meteorology plays a major role in determining air quality changes downwind of emission sources. Both the wind and atmospheric stability greatly affect dispersion. Local influences due to terrain and land-cover factors are also important. Meteorological input to CALPUFF is generated by the CALMET pre-processor. Inputs to CALMET include a five-year (2002-2006) meteorological data set for the modelling domain from ESRD. The set of meteorological data is the result of MM5 modelling. MM5 is a widely used research and regional forecasting model based on the NCAR-PSU model. MM5 uses global weather observations as its input to generate gridded meteorological data. The CALMET modelling was completed over an area of 40 by 40 km. The meteorological modelling domain is much larger than the CALPUFF modelling domain to ensure that the CALPUFF model uses the most representative wind fields across the entire study area. The CALMET model contains several options for calculating the domain wind field. As in CALPUFF, all the modelling options used in the model are default as recommended by the AQMG. 2.7.2.1 Wind The CALMET-derived winds for the Project area are presented in Figure 3. The lengths of the bars on the wind rose indicate the frequency and speed of wind, and the direction from which the wind blows is illustrated by the orientation of the bar in one of 16 directions. The CALMET winds for the 0.5 by 0.5 km grid cell containing the Project indicate that the predominant winds are from the southwest with a secondary predominance from the west.

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Figure 3 CALMET-Derived Windrose for the Project Area (2002 to 2006)

2.7.2.2 Temperature The CALMET-derived temperatures for the Project area are presented in Table 3 and Figure 4. The temperatures range from -34.1 to +37.5°C, with a median value of +5.58°C.

Table 3 Temperature (◦C) Derived from CALMET for the Project (2002 to 2006)

1 2 3 4 5 6 7 8 9 10 11 12 Min -33.5 -31.3 -34.1 -21.3 -6.85 1.25 4.45 3.79 -6.25 -18.8 -29.6 -26.8 25th percentile -14.6 -8.64 -8.83 1.46 5.98 11.9 16.3 13.3 7.60 -0.11 -5.98 -9.17 50th percentile -4.58 -4.02 -1.9 5.44 10.4 15.2 19.4 17.1 10.8 4.22 -1.37 -3.80 75th percentile -1.12 -0.81 -5.07 4.77 14.1 22.3 25.7 19.7 16.0 5.96 4.72 1.39 Max 0.715 -0.41 2.99 8.89 14.6 18.7 22.7 20.4 14.7 8.68 2.71 0.485

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BowArk Generation Plant 5% - 95% 25% - 75% 40

C) 10 ◦

Temp ( 0

-10

-20

-30 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Month

Figure 4 CALMET-Derived Temperature for the Project Area (2002 to 2006)

2.7.2.3 Stability Class Atmospheric stability can be viewed as a measure of the atmosphere’s turbulence related to atmospheric disperse. The amount of turbulence plays an important role in the dilution of a plume as it is transported by the wind.

Turbulence can be generated by either thermal or mechanical mechanisms. Surface heating or cooling by radiation contributes to the generation or suppression of thermal turbulence, while high wind speeds contribute to the generation of mechanical turbulence.

The Pasquill-Gifford (PG) stability classification scheme is one classification of the atmosphere. The classification ranges from Unstable (Stability Classes A, B and C), Neutral (Stability Class D) to Stable (Stability Classes E and F). Unstable conditions are primarily associated with daytime heating conditions which result in enhanced turbulence levels (enhanced dispersion). Stable conditions are associated primarily with night time cooling conditions, which result in suppressed turbulence levels (poorer dispersion). Neutral conditions are primarily associated with higher wind speeds or overcast conditions.

The stability conditions derived by CALMET for the Project area are summarized as follows and presented in Table 4 and Figure 5:

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• unstable (A, B and C) conditions occur 24.6% of the time; • neutral conditions occur 43.7% of the time; and • stable (E and F) conditions occur 31.7% of the time.

Table 4 CALMET Derived PG Stability Class Frequency at the Project (2002- 2006)

PG Class Frequency A 1.41% B 8.94% C 14.2% D 43.7% E 17.6% F 14.1%

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Spring Summer 100% 100% 90% 90% 80% 80% F F 70% 70% 60% E 60% E 50% D 50% D 40% C 40% C 30% B 30% B 20% 20% A A 10% 10% 0% 0% 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Fall Winter 100% 100% 90% 90% 80% 80% F F 70% 70% 60% E 60% E 50% D 50% D 40% C 40% C 30% B 30% B 20% 20% A A 10% 10% 0% 0% 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Figure 5 Frequency of Predicted PG Stability Class at the Project (2002- 2006)

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2.7.2.4 Mixing Height Mixing height is a measure of the depth of the atmosphere through which mixing of emissions can occur. Mixing heights often exhibit a strong diurnal and seasonal variation: they are lower during the night and higher during the day. Seasonally, mixing heights are typically lower in the winter and higher in the spring and summer. The median mixing heights in spring, summer, fall and winter are about 351, 443, 170 and 91.5 m, respectively. The frequency of diurnal mixing heights derived by CALMET for the Project is presented in Table 5 and Figures 6 and 7. The daytime mixing heights are generally higher than the nighttime mixing heights. The average nighttime mixing height is 192 m and the average daytime mixing height is 651 m. In the model, the minimum and maximum mixing heights were set to 50 and 3,000 m, respectively. Table 5 Predicted Seasonal Mixing Height (m) Derived for the Project

MIN 25%ile MEDAIN 75%ile MAX

Spring 50.0 153 351 817 2287 Summer 50.0 146 443 1388 3000 Fall 50.0 73 170 464 2686 Winter 50.0 51.6 91.5 166 1612

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3500 3000

Day Time Night Time 3000 2500

2500

2000

1500 Mixing Height (m)

Mixing Height (m) 1500

1000

500

0 30% 0% 30% 60% 0 Frequency of Occurrence Day time Night Time

Figure 6 CALMET-Derived Mixing Heights for the Project Area (2002 to 2006)

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Spring Summer 2500 3500

3000 2000 2500

1500 2000

1500 1000

Mixing Height (m) Mixing Height (m) 1000 500 500

0 0 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 Hour Hour

Fall Winter 3000 1800

1600 2500 1400

2000 1200

1000 1500 800

Mixing Height (m) 1000 Mixing Height (m) 600

400 500 200

0 0 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 Hour Hour

Figure 7 CALMET Predicted Mixing Height for Different Seasons and Times of Day at Project (2002 to 2006)

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2.7.2.5 NOX to NO2 Conversion Method

Nitrogen oxides are comprised primarily of NO and NO2. Ambient air quality criteria exist for NO2 rather than total NOX, but emission data is provided as total NOx emissions therefore the modeling predicts concentrations of total NOx, not NO2 directly. Therefore, it is important to be able to estimate the portion of predicted ground-level NOX comprised of NO2. The Alberta AQMG recommends five methods for determining the amount of NO2 formed from NOX, including the total conversion method, the plume volume molar ratio method (PVMRM), the CALPUFF RIVAD/ARM3 chemical formulation, the ozone limiting method and the ambient ratio method.

For this assessment, predicted NOx concentrations are small, much lower than the AAQO, therefore the total conversion method is used to convert NOx to NO2 concentrations. 2.7.2.6 Building Downwash Building or solid structure may affect the flow of air in the vicinity of a source and cause eddies to form on the downwind side of a building. According to the AQMG, the effects of local buildings should be considered when conducting a dispersion modelling assessment. The Building Profile Input Program (BPIP) was used to evaluate the effect of buildings in the vicinity of the proposed Project stack. The building dimensions were summarized in Table 6.

Table 6 Buildings Dimensions for the Project

Buildings H (m) L (m) W (m) BLDG1 15 22 6.1 BLDG2 3 3 3.0

2.7.2.7 Presentation of Modelling Results To aid in the interpretation of the dispersion modelling, the results are presented in a tabular format which allows comparison between the predictions and relevant Alberta AAQOs. The CALPUFF modelling used five years of meteorological data, therefore, for each pollutant modelled, the maximum 1-hour, 24-hour and annual average concentrations were predicted for each year, separately. The highest value of the five years is presented. The 1-hour concentration results are presented as ninth highest concentrations. The maximum predicted 9th highest concentrations represent results when the eight highest 1-hour model predictions are excluded. The AQMG recommends that the eight highest 1-hour model predictions in a year should be excluded when determining compliance with the Alberta AAQO values for the 1-hour averaging period. Conversely, the eight highest 1-hour predicted average concentrations for each receptor are included when calculating, second highest 24-hour and maximum annual average concentrations. Based on ESRD (2013b, 2013c), the second highest 24-hour concentration value should be used when determining compliance with the Alberta AAQOs for the 24-hour averaging period.

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2.8 Air Quality and Emissions Criteria 2.8.1 Ambient Air Quality A range of effects may result from air emissions introduced into the atmosphere by industrial activities. The emissions can have direct and indirect effects on humans, animals, vegetation, soil and water. For these reasons, environmental regulatory agencies have established maximum ambient air concentration limits. This section provides an overview of the relevant air quality criteria for this assessment. The focus of this assessment is on air quality compounds for which there are Alberta AAQOs that are emitted by the Project and within the region. The applicable Alberta AAQOs are presented in Table 7. Table 7 Alberta Ambient Air Quality Objectives

AAQO Pollutants Averaging Period (µg/m3)

NO2 1-hour 300 Annual 45 CO 1-hour 15,000 8-hour 6,000

3.0 PROJECT-ONLY CASES 3.1 Introduction The evaluation of air quality effects associated with the Project requires consideration of emissions from other sources within 5 km area in combination with those from the Project. In this assessment effect of emissions from the proposed plant are assessed. The Project-only Case considers the effect of emissions from the proposed stacks. These emissions are described in the following sections. 3.2 Project Emissions The Project–only Case represents the air quality conditions expected to result from the proposed plant.

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Table 8 presents the source parameters and emission rates for each individual source at the Project. The emissions from the water heater are added to Unit 2 due to the lack of unit-specific stack information.

Table 8 Project Emissions

Unit 1 Unit 2 Water Heater UTM mN 5607583 5607559 5,607,595 UTM mE 356706 356706 356,688 Generator Gross Output (kW) 45040 45040 261 Exhaust Mass Flow Rate Wet (kg/sec) 124.0 124.0 - Exhaust Temp (deg C) 502.2 502.2 - Molar Weight (kg/kmole) 28.6 28.6 - Exhaust Pressure (kPa(a)) 89.886 89.886 - Exhaust Density (kg/m3) 0.4422 0.4422 - Stack Volumetric Flow Rate (m3/sec) 283.2 283.2 - Stack ID (m) 2.7432 2.7432 - Stack Exit Velocity (m/s) 47.92 47.92 - Stack Height (m) 18.288 18.288 - Emissions (g/sec) NOx 2.77 2.77 3.85E-02 CO 2.81 2.81 1.16E-02

3.3 Project-only Case Predictions

3.3.1 NO2 Predictions th The NOX emissions from the proposed stacks are 0.482 t/d. The 9 highest 1-hour and maximum annual ground-level NO2 concentrations resulting from the emissions associated with the proposed sources were predicted using the CALPUFF dispersion model.

Isopleth maps show the locations of the maximum concentrations and the dispersion patterns (in Appendix A).

Results of the Project case are shown in Table 9 and are summarized below.

th • The 9 highest 1-hour predicted NO2 concentration in the study area excluding developed areas is 19.5 μg/m³. • The maximum annual predicted concentration excluding developed areas in the study area is 7.44 μg/m³.

th • The 9 highest 1-hour NO2 prediction is located at the 0.2 km east of the Project boundary. The maximum annual NO2 prediction is located at 0.1 km north of the Project Boundary.

th • The 9 highest 1-hour and maximum annual predicted NOx concentrations are similar as those for NO2 due to the low NOx concentrations.

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Table 9 Project-only Case NO2 Predictions

Background Project- Project + Averaging Concentrations only Background AB AAQOs Contaminant Period (μg/m3) (μg/m3) (μg/m3) (μg/m3) 1-hour 15 4.48 19.5 300

NO2 Annual 7.39 0.0512 7.44 45

3.3.2 CO Predictions The CO emissions from the proposed stacks are 0.486 t/d. The 9th highest 1-hour and 2nd highest 8-hour ground-level CO concentrations resulting from the emissions associated with the proposed source were predicted using the CALPUFF dispersion model

Isopleth maps show the locations of the maximum concentrations and the dispersion patterns (in Appendix A).

Results of the Baseline case are shown in Table 10 and are summarized below.

• The 9th highest 1-hour predicted CO concentration in the study area excluding developed areas is 234 μg/m³. • The 2nd highest 8-hour predicted concentration excluding developed areas in the study area is 248 μg/m³. • The 9th highest 1-hour CO prediction is located at the 0.2 km east of the Project boundary. The 2nd highest 8-hour CO prediction is located at 0.2 km north northwest of the Project Boundary. Table 10 Project Case CO Predictions

Background Project + Background Averaging Concentrations Project-only 3 AB AAQOs Contaminant Period (μg/m3) (μg/m3) (μg/m ) (μg/m3) 1-hour 229 4.51 234 15,000 CO 8-hour 245 3.49 248 6,000

4.0 CUMULATIVE CASE 4.1 Introduction The Cumulative Case includes sources from the industrial facilities within 5 km area in combination with the Project. Only one facility, Husky compressor station 06-01-19-23W4 is within 5 km range. The source parameters and emission rates for this station is provided in Table 11. NPRI data and genetic stack parameters are used for this station due to lack of facility-specific information.

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Table 11 Background Facility Emissions

Husky Compressor Station UTM mN 5,604,813 UTM mE 353,353 Exhaust Temp (deg C) 500 Stack ID (m) 0.5 Stack Exit Velocity (m/s) 25 Stack Height (m) 10 Emissions (g/s) NOx 0.82 CO 0.24

4.2 Cumulative Case Predictions

4.2.1 NO2 Predictions The existing sources within 5 km area from the Project in combination with the Project result in

an additional 0.071 t/d of NOX being emitted to the atmosphere.. The maximum 1-hour and

annual ground-level NO2 concentrations resulting from the emissions associated with the existing industrial combustion sources in the area were predicted using the CALPUFF dispersion model. The maximum predicted concentrations with the background ambient concentrations are compared to the relevant regulatory objectives.

Isopleth maps show the locations of the maximum concentrations and the dispersion patterns (in Appendix A).

Results of the Baseline case are shown in Table 12 and are summarized below.

th • The 9 highest 1-hour predicted NO2 concentration for the Cumulative Case in the study area excluding developed areas is 29.2 μg/m³, which is below the AAAQO of 300 μg/m³. • The maximum annual predicted concentration for the Cumulative Case in the study area excluding developed areas in the study area is 7.75 μg/m³, which is above the AAAQO of 45 μg/m³.

th • The 9 highest 1-hour NO2 prediction is located at the 2.7 km south southwest of the Project boundary. The maximum annual NO2 prediction is located at 3.0 km south southwest of the Project Boundary.

th • The 9 highest 1-hour and maximum annual predicted NOx concentrations are similar as those for NO2 due to the low NOx concentrations.

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Table 12 Cumulative Case NO2 Predictions

Background Project + Averaging Concentrations Project-only Background AAQO Contaminant Period (μg/m3) (μg/m3) (μg/m3) (μg/m3) 1-hour 15 14.2 29.2 300

NO2 Annual 7.39 0.358 7.75 45

4.2.2 CO Predictions The existing sources within 5 km area from the Project in combination with the Project result in 0.507 t/d of CO being emitted to the atmosphere. The CO emissions from existing Husky compressor station are 0.021 t/d. The CO emissions from the proposed stacks are 0.486 t/d. The maximum 1-hour and 8-hour ground-level CO concentrations resulting from the emissions associated with the existing industrial combustion sources in the area were predicted using the CALPUFF dispersion model. The maximum predicted concentrations with the background ambient concentrations are compared to the relevant regulatory objectives.

Isopleth maps show the locations of the maximum concentrations and the dispersion patterns (in Appendix A).

Results of the Baseline case are shown in Table 13 and are summarized below.

• The 9th highest 1-hour predicted CO concentration in the study area excluding developed areas is 234 μg/m³, which is below the AAAQO of 15,000 μg/m³. • The highest 8-hour predicted concentration excluding developed areas in the study area is 248 μg/m³, which is below the AAAQO of 6,000 μg/m³. • The 9th highest 1-hour CO prediction is located at the 2.7 km south southwest of the Project boundary. The maximum 8-hour CO prediction is located at 0.2 km north northwest of the Project Boundary. Table 13 Cumulative Case CO Predictions

Background Project + Averaging Concentrations Project-only Background AB AAQOs Contaminant Period (μg/m3) (μg/m3) (μg/m3) (μg/m3) 1-hour 229 4.51 234 15,000 CO 8-hour 245 3.49 248 6,000

5.0 CONCLUSIONS

The modelling results demonstrate that the predicted concentrations of NO2 and CO are in compliance with the Alberta AAQOs for the corresponding averaging periods.

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6.0 REFERENCES 6.1 Literature Cited ESRD . 2013a. Alberta Ambient Air Quality Objectives and Guidelines Summary. Environmental Protection and Enhancement Act.

ESRD . 2013b. Air Quality Model Guideline. Air Policy Section.

ESRD . 2013c. Using Ambient Air Quality Objectives in Industrial Plume Dispersion Modelling and Individual Industrial Site Monitoring. Air Policy Section.

CASA (Clean Air Strategic Alliance). 2003. An Emissions Management Framework for the Alberta Electricity Sector Report to Stakeholders. Prepared by the Clean Air Strategic Alliance electricity Project Team.

Canadian Digital Elevation Data (CDED). 2011. Available at: http://www.geobase.ca/geobase/en/data/cded/index.html. . Accessed: January 2013.

Scire, J.S., D.G. Strimaitis and R.J. Yamartino. (2000). A User’s Guide for the CALPUFF Model (Version 5.0). Earth Technologies Inc. Concord, MA.

6.2 Internet Sites and Personal Communications CASA (Clean Air Strategic Alliance). 2013. Air quality data downloaded for the WBEA monitoring stations. Available at http://www.casadata.org/Reports/SelectCategory.asp. Accessed October 2013.

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Appendix A

Figures

Attachment G

Participant Involvement Program

Queenstown Power Plant

Peaking Power Plant for Alberta’s Changing Power Requirements

May 2014

Queenstown Power Plant

A New Peaking Generation Facility for Alberta

BowArk Energy Ltd. is proposing to build the Queenstown Power Plant, a simple cycle natural gas‐fired peaking power plant, and the McGregor substation. BowArk Energy, along with potential partner(s), plans to construct and operate the Project on a site adjacent to the existing Altalink 504s Queenstown Substation at the intersection of Range Rd 225 and Township Rd 192 in the County of Vulcan. The project’s generation capacity shall be 98 megawatts (MW). The in‐service date is currently Late 2016. The expected life of the natural gas facility is approximately 35 years.

The project is to be located on the SW1/4 of Section 17, Township 19, Range 22, West of the 4 Meridian in the County of Vulcan approximately 58 km East of High River and 3.3 km North of Highway 542 and 7.5 km southwest of the hamlet of Queenstown. The Power Plant will be constructed on a Greenfield (Pasture Land) site and comprise an area of less than 3.5 acres. Immediately to the West of the Power Plant will be the McGregor Substation which will abut the adjacent Existing Altalink 504s Queenstown Substation and comprise an area of 1 acre.

Helping Meet Alberta Unique Power Needs

The power project is being developed to meet Alberta’s unique future power needs and the increasing concentration of renewable power generation in the province. Requirements for new generation are being supported by economic growth and the retirement of Alberta substantial coal fired fleet by 2030, coal generation currently representing 40% or 6271 MW of Alberta total installed power generation capacity. Compounding the need for new dispatch‐able fast acting generation within the province is a significant increase in wind generation. Wind generation can not be dispatched to meet varying load requirements throughout the day, rather, this type of generation demands additional fast acting dispatch‐able generation resources to respond to uncontrollable generation changes associated with wind speed changes. BowArk is designing this plant specifically to meet the rapid generation response requirements of Alberta future grid. A plant which will be capable of rated output with only 10 minutes notice and equipped to participate in the numerous ancillary services required to support the changing grid demands. The plant has been strategically located close to the Calgary and High River load centres to minimize transmission losses and adjacent to existing transmission infrastructure to minimize the requirement for added transmission lines.

Generation Technology

The plant will be comprised of two natural gas fired, 49 megawatt (MW), General Electric, LM6000, turbine generator sets operating in simple or open cycle. The plant being open cycle requires no water for cooling nor discharges any waste cooling water.

Electricity generated by each of the two identical generators will be transmitted from the project’s new McGregor substation to the Altalink existing 504s Queenstown substation immediately West of the generation site. The resultant new 138kV transmission circuit will run approximately 70 meters (m) on lands owned by BowArk and Altalink. Regulatory approval of this transmission circuit is via a separate process. Interconnection within Altalink 504s substation will be facilitated by an existing 138 kV bus position which was abandoned as a result of the Southern Transmission Reinforcement system project.

Natural gas will be supplied to the plant via a high pressure buried 7.5 km transmission line which will be connected to TransCanada’s existing line. Separate regulatory approval will be required for this gas line.

Environmental Performance

Fired on natural gas the plant will incorporate advanced emission controls systems providing clean, reliable, flexible and responsive generation. The General Electric LM6000 PF generator set proposed for this project incorporates the most advanced emission control technology GE offers in this work horse unit with total Nitrogen Oxide (NOx) production of 15 part per million (ppm). The advanced dry low NOx combustion system of the LM6000 PF utilizes a staged burner system to achieve extremely low emission level thus avoiding requirements for makeup water typical of other emission control systems. Further, as the engines are open or simple cycle, there is no need for cooling water typically required of combined cycles. Generator and auxiliary cooling will also be via dry closed aerial coolers, further conserving limiting water resource consumption.

Participant Involvement Program

BowArk Energy Ltd. is committed to sharing information on the Project and receiving input from our neighbours and stakeholders. BowArk has commenced this process by developing several opportunities for information exchanges. These include:

 Project information mailed to local landowners and other stakeholders.  Project information on BowArk Energy’s Web Site (www. Bowark.com).  Face to face meeting with local land owners and stakeholders.

Project Schedule

BowArk Energy anticipates submitting regulatory application for the Project in the fall of 2014. Applications will be made to the Alberta Utilities Commission and Alberta Environment and Sustainable Resource Development. Prior to construction we will be applying to the County of Vulcan for all necessary development and building permits.

Neither Provincial nor County land use restrictions nor setbacks are anticipated for lands adjacent to the Queenstown Power Plant development as a result of the Queenstown Power Plant development.

BowArk has commissioned numerous environmental and historical land use studies to facilitate the various applications including but not limited to: air quality, water, soil, wildlife, noise and cultural heritage. We will be posting the results of these studies on out web site (www.bowark.com) as they are published for stakeholder review and communicating personally with stakeholders directly affected by the results.

BowArk started the regulatory electrical interconnection process for this project in 2012 and anticipates Alberta Utility Commission Permit and License for electrical interconnection to be issued early in 2015. Interconnection of this project is subject to Alberta Electric System Operator (AESO) and Altalink’s (Transmission Facility Owner) completion of local area transmission improvements expected to be complete early in 2016.

Pending a successful outcome of the regulatory review, we anticipate construction to begin early in 2016. Construction is anticipated to be complete within the year with commercial operation late in 2016.

We Want to Hear From You

BowArk Energy values your input into the proposed Queenstown Power Plant. We have launched a participation involvement program to share information with stakeholders and obtain input on our proposal.

Contact by phone or email:

Shelley Sammartino Direct: (403) 237‐0211 Email: [email protected]

Contact by mail: BowArk Energy Ltd. Suite 4301, 400 3rd Ave SW Calgary, Alberta T2P 4H2

Website: www.bowark.com

Public Involvement In Needs Or Facilities Applications The Alberta Utilities Commission (AUC) is committed to ensuring that Albertans whose rights may be directly and adversely affected by a needs, or a utility facilities application, are informed of the application and have the opportunity to have their concerns heard, understood and considered.

If you believe an application may directly and adversely affect you, you can become involved in the AUC application process. This pamphlet explains how.

www.auc.ab.cawww.auc.ab.ca Summary of the AUC application process

Step 1 Public consultation (prior to application to the AUC) Step 2 Application made to the AUC Step 3 AUC issues notice of application (or hearing) Step 4 Interested parties make submissions or objections (If no submissions are made the AUC will continue to process the application) Step 5 Opportunity for consultation and negotiation

AUC issues notice of hearing (if not already issued in Step 3) Step 6 Public hearing

Step 7 AUC decision

Needs: Approval of application or Return to applicant or Denial of application

Facilities: Approval of application or Approval of application with conditions or Denial of application

Step 8 Right to appeal (by applicant or dissatisfied persons)

Step 9 Approvals, construction and operation of facility (if approved)

2 AUC’s role in needs and facilities applications

The Alberta Utilities Commission (AUC or Commission) regulates transmission lines, electric substations, power generation facilities (i.e. power plants including wind turbines) and gas utility pipelines in Alberta. The AUC is committed to ensuring that Albertans whose rights may be directly and adversely affected by an application for these facilities are informed of the application and have the opportunity to have their concerns heard, considered and understood.

Transmission needs and utility facilities applications

Approvals from the AUC are required for the construction, operation, alteration and decommissioning of transmission lines and electric substations. These include:

· Approval of the need for transmission upgrades.*

· Approval of the route and location of transmission facilities.

(* The Electric Statutes Amendment Act gives the provincial cabinet responsibility for approving the need for specified critical transmission infrastructure projects.)

Sometimes an application for needs approval is considered together with an application for a utility facilities approval in a single hearing, or separate hearings may be held to consider each application.

Power generation facilities and gas utility pipelines

Approvals from the AUC are required for the construction, operation, alteration and decommissioning of power generation and gas utility pipeline facilities in Alberta. Facilities: Approval of application or Approval of application with conditions or Denial of application If you believe that you have rights that may be directly and adversely affected by the decision of the AUC on an application relating to a transmission line or electric substation, a power generation facility or a gas utility pipeline you can become involved in the AUC application process. This pamphlet explains how.

A summary of our process is on the page to the left. The rest of this brochure explains each of the steps.

3 Step 1: Public consultation prior to application

Prior to making an application to the Commission on the need for transmission changes, or for a proposed facility, the applicant is required to conduct meaningful public consultation in the area of the proposed needs, or facilities project(s), so that concerns may be raised, properly addressed and if possible, resolved.

The Commission has set out requirements for applicants to follow regarding public consultation about needs applications for transmission changes. The AUC also has requirements for public consultation for utility facilities applications in respect of power plants, substations, transmission lines and industrial system designations, set out in AUC Rule 007. The requirements for gas pipeline consultation and notification are set out in AUC Rule 020. AUC Rule 007 and Rule 020 can be found on the AUC website at www.auc.ab.ca.

Potentially-affected parties are strongly encouraged to participate in the initial public consultation, as early involvement in informal discussions with an applicant may lead to greater influence on project planning.

4 Step 2: Application to the Alberta Utilities Commission

After the applicant has conducted its public consultation process, it should take into consideration what it learned during consultations and make any amendments it sees as necessary and reasonable to its proposal. The applicant then makes an application to the Alberta Utilities Commission.

Applicants must identify in their application any unresolved objections or concerns that they are aware of from the public consultation process.

Meaningful public participation through a fair, open and transparent process is important and necessary if the AUC is to reach sound and principled decisions.

5 Parties wanting to become a participant in an AUC proceeding must make a written submission to the AUC.

Step 3: Public notification

The Commission will issue a notice of application when it receives an application that, in the Com- mission’s opinion, may directly and adversely affect the rights of one or more people. The notice is typically published in local newspapers. The notice will provide key dates, contacts and information on how to participate for those who are interested in becoming involved in the application process.

Step 4: Public participation

If you wish to participate in a proceeding, you must make a written submission to the Commis- sion in accordance with the AUC’s notice of application.

Submissions must contain: • A brief description of your concern with or interest in the application, in particular how approval of the application may directly and adversely affect you.

• A brief explanation of your position, on what decision you feel the AUC should take, including why you believe that the Commission should accept your recommendation.

The Commission will consider your submission and decide whether you are a person who may be directly and adversely affected by the proposed project. If you are, an AUC public hearing may be held.

6 Please be aware that any information and materials you provide as part of an AUC proceeding, except information granted confidentiality, will become part of the public record and will be posted to the AUC’s electronic filing system. This includes personal information, such as your name, address and any other personal information you provide.

AUC filing systems Documents associated with applications are stored and accessed through the AUC’s electronic filing systems. The AUC would appreciate receiving submissions through its electronic filing services on our website, however submissions may also be made through mail, email or fax. More information on the electronic filing services can be found on the AUC’s website at www.auc.ab.ca or by calling Electronic Filing Services. Please see the back cover of this pamphlet for contact information.

Financial assistance If a party may be potentially directly and adversely affected by a proposed facility, they can apply to be reimbursed for reasonable costs incurred in support of their participation in a Commission proceeding. Details regarding recovery of participants’ costs are described in AUC Rule 009: Rules on Local Intervener Costs, available on the AUC’s website at www.auc.ab.ca.

7 Step 5: Consultation and negotiation

The Commission supports ongoing efforts to reach a positive outcome for the applicant and all affected parties. The Commission encourages the applicant and those who have filed submissions to continue to attempt to resolve any outstanding issues.

Sometimes in utility facilities applications, the applicant may suggest that it enter into an alternative dispute resolution (ADR) process to resolve any outstanding issues. In an ADR process, the applicant and the participants agree to meet with an independent third party who will facilitate discussions between the parties in an attempt to reach an agreement.

8 ADR is neither mandatory nor binding on either party. However, it can be an effective tool to try and resolve issues in an amicable environment and manner. If all concerns can be satisfactorily resolved this may eliminate the need for a formal hearing. However, if there continue to be unresolved issues after further discussions with participants, typically those matters will be addressed at an AUC public hearing.

Early involvement in discussion with the applicant may lead to greater influence on project planning.

9 Step 6: The public hearing process

The public hearing process provides an opportunity for those who were unable to resolve their concerns with the applicant to express their views directly to a Commission panel. Those persons who the Commission has determined may be directly and adversely affected by the proposed application are entitled to participate in the hearing.

The Commission publishes a notice of hearing in newspapers distributed in the local area, in major Alberta daily newspapers and on the AUC website at www.auc.ab.ca. Copies of the notice are also mailed to the applicant and participants.

The notice of hearing sets out the deadlines for various steps in the process, including the process and timelines for filing written submissions and for preparing questions to be answered by the applicant or other participants.

An AUC public hearing operates similarly to a court proceeding and is a quasi-judicial process. The hearing is open to the general public.

Participants in a hearing can either represent themselves or be represented by legal counsel. In addition, participants may hire experts to assist in preparing and presenting evidence to support their position.

Persons who hire legal counsel or technical experts must be aware that while reimbursement for the costs of legal and technical assistance may be available, recovery of costs is subject to the Commission assessing the value of the contribution provided by counsel and technical experts. People with similar interests and positions are expected to work together to ensure that any expenditures on outside legal or technical assistance are efficiently spent and not duplicated.

10 Step 7: The decision

After hearing a needs application the Commission either approves the application, denies the application, or sends the application back to the applicant with suggestions for change.

After hearing a utility facilities application, the AUC has three options in reaching a decision: approve the application as applied for, approve it with conditions, or deny it. The AUC endeavors to release decisions within 90 days from the close of the record. Decisions are issued in the form of a public written decision report that summarizes the Commission’s findings and includes its final decision.

All Commission decision reports are available to any member of the public on the Commis- sion’s website (www.auc.ab.ca) or by calling the AUC’s Information Services. Please see the back cover of this pamphlet for contact information.

11 Step 8: Right to appeal

A participant in a hearing who is dissatisfied with the decision of the Commission may request that the Commission review and vary its decision. Such a request must follow the procedure set out in the Commission’s Rule 016: Review and Variance of Commission Decisions. A dissatisfied participant may also file a leave to appeal motion in the Court of Appeal of Alberta within 30 days from the date the decision is issued.

All Commission decision reports are available to any member of the public on the Commission’s website (www.auc.ab.ca) or by calling Information Services. See the back cover of this pamphlet for contact information.

12 Step 9: Construction and operation

Any applicant that receives a licence or permit to build and operate a facility from the Commission must adhere to any conditions that were set out in the Commission’s decision. If you notice something during the construction or operational phases of a project that concerns you, bring this to the applicant’s attention. If you are not satisfied with the response you receive, please bring your concerns to the attention of the AUC Consumer Relations. See back cover of this pamphlet for contact information.

13 Useful resources:

- Rule 001: Rules of Practice

- Rule 007: Rules Respecting Applications for Power Plants, Substations,

Transmission Lines, and Industrial System Designations

- Rule 009: Rules on Local Intervener Costs

- Rule 020: Rules Respecting Gas Utility Pipelines

- About the AUC brochure - AUC electronic filing services brochure - Local intervener costs brochure - Understanding gas utility pipeline regulation in Alberta

14 Notes:

15 AUC contact information: Other contacts:

Facilities Division Surface Rights Board Phone: 403-592-4403 and ask to speak (Land Compensation and Negotiation) to the Facilities Division Phone: 780-427-2444 www.surfacerights.gov.ab.ca Consumer Relations Phone: 780-427-4903, or Alberta Environment Email: [email protected] (Land Conservation and Reclamation) Phone: 780-427-2700 Information Services www.environment.alberta.ca Phone: 403-592-4500, or Email: [email protected] Alberta Electric System Operator (AESO) Electronic Filing (E-Filing) Services Phone: 1-888-866-2959 Phone: 780-643-1055, or www.aeso.ca Email: [email protected]

Calgary - Head Office Fifth Avenue Place East Fourth Floor, 425 First Street S.W. Calgary, Alberta T2P 3L8 Phone: 403-592-8845* Fax: 403-592-4406

Edmonton Office HSBC Building Tenth Floor, 10055-106 Street *Dial 310-0000 prior to the 10 digit numbers Edmonton, Alberta T5J 2Y2 for toll-free access anywhere in Alberta. Phone: 780-427-4901* Fax: 780-427-6970 This brochure provides general information about public involvement in needs and utility facilities applications before the AUC. Specific participation www.auc.ab.ca opportunities and requirements may differ depending on the type of application.

Updated January 2013

Attachment H

Historical Resources Act Clearance

Historic Resources Application Activity Administration September 10, Date Received: HRA Number: 4940-14-0079-001 2014

Project Category: Transmission Lines and Electrical Power Generation (4940)

Application Purpose: ; Requesting HRA Approval / Requirements

Lands Affected ; All New Lands

Project Type: ; Power Plant ESRI Shapefiles are attached yes ; Substation (new) (yes/no) Approximate Project Area (ha) 4.5 Other Reference Number CE04460

Project Name: BowArk Queenstown Power Generation Plant Additional Name(s):

Key Contact: Ms Nancy Saxberg Affiliation: AMEC Environment & Infrastructure Address: 140 Quarry Park Blvd. SE City / Province: Calgary, AB Postal Code: T2C 3G3 Phone: (403) 387-1759 E-mail: [email protected] Fax: () - Your File Number: CE04460

Proponent: BowArk Energy Ltd. Contact Name: Pat Bowes Address: Suite 4301 Devon Tower 400 -3rd Ave SW City / Province: Calgary, AB Postal Code: T2P 4H2 Phone: (403) 264-2259 E-mail: [email protected] Fax: () -

Proposed Development Area Land Ownership MER RGE TWP SEC LSD List FRH SA CU CT 4 22 19 17 3-6 ;

HRA Number: 4940-14-0079-001 Page 1 of 2 Historical Resources Impact Assessment: For archaeological resources: Has a HRIA been conducted? Yes ; No Permit Number (if applicable): For palaeontological resource: Has a HRIA been conducted? Yes ; No Permit Number (if applicable):

Historical Resources Act clearance is granted subject to Section 31 of the Resources Act, "a person who discovers an historic resource in the course of making an excavation for a purpose other than for the purpose of seeking historic resources shall forthwith notify the minister of the discovery". The chance discovery of historical resources is to be reported to the contacts identified within the listing.

September 19, 2014 Date

HRA Number: 4940-14-0079-001 Page 2 of 2