Connection Engineering Study Report for AUC Application: EPCOR Victoria Substation E511S Breaker Addition

Executive Summary

Project Overview EPCOR Distribution & Transmission Inc. (EDTI), in its capacity as the legal owner of an electric distribution system (DFO), submitted a system access service request to the Alberta Electric System Operator (AESO) to reliably serve new loads in downtown Edmonton. The DFO’s request for system access service includes a request for a Rate DTS, Demand Transmission Service, contract capacity increase of approximately 6 MW (from 133.92 MW to 140 MW) at the existing Victoria substation, and a request for transmission development (collectively, the Project). Specifically, the DFO requested modifications to the existing Victoria substation. The scheduled in-service date (ISD) for the Project is March 13, 2017. This report details the engineering studies undertaken to assess the impact of the Project on the performance of the Alberta interconnected electric system (AIES).

Existing System The Project is located in the AESO planning area of Edmonton (Area 60). Edmonton (Area 60) is surrounded by the planning areas of Fort Saskatchewan (Area 33), Athabasca/Lac La Biche (Area 27), Wabamun (Area 40), and Wetaskiwin (Area 31). From a transmission system perspective, Edmonton (Area 60) consists of 240 kV, 138/144 kV, and 69/72 kV transmission systems. The Victoria substation is connected to the Castle Downs substation by the 240 kV transmission line 240CV5, and is connected to the Rossdale substation by the 72 kV transmission lines 72RV4, 72RV6 and 72RV2. The Castle Downs substation connects to the North Calder 37S and Lamoureux 71S substations via the 240 kV transmission line 920L. The Victoria substation connects to the Argyll Transfer Station through the Bellamy substation. Existing constraints in the Edmonton Planning Region are managed in accordance with the procedures set out in Section 302.1 of the ISO rules, Real Time Transmission Constraint Management.

Study Summary

Study Area The Study Area for the Project consists of Edmonton (Area 60), including the tie lines connecting this planning area to neighbouring planning areas. All transmission facilities within the Study Area were studied and monitored to assess the impact of the Project on the performance of the AIES, including any violations of the Reliability Criteria (as defined in Section 2.1.1).

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Studies Performed

Power flow studies were performed for the 2017 summer peak (SP) and winter peak (WP) pre- Project and post-Project scenarios. Voltage stability analysis was performed for the 2017 SP and 2017 WP post-Project scenarios.

Results of Pre-Project studies

The following is a brief summary of the pre-Project studies results. The pre-Project studies results and applicable mitigation measures are shown in greater detail in Table E-1 below.

Category A conditions (N-G-0) No Reliability Criteria violations were observed under Category A conditions for any of the pre- Project scenarios.

Category B contingency conditions (N-G-1) The pre-Project power flow studies identified a number of system performance issues, namely thermal criteria violations, under Category B contingency conditions.

Connection Alternatives Examined for the Project

The AESO, in consultation with the DFO and the legal owner of transmission facilities, examined three transmission alternatives to meet the DFO’s request for system access service. Each of the transmission alternatives involves the addition of two 15 kV distribution feeders to serve the new loads and a third 15 kV distribution feeder to provide standby capability.

Alternative 1 – Modifications at the Victoria substation (two 15 kV circuit breakers)

Alternative 1 involves modifying the existing Victoria substation, including adding two 15 kV circuit breakers to accommodate the addition of two 15 kV distribution feeders.

EDTI has advised that there is an existing spare 15 kV circuit breaker at the Victoria substation, which can be used to connect a third 15 kV distribution feeder.

Alternative 2 – Modifications at the Rossdale substation

Alternative 2 involves modifying the existing Rossdale substation, including adding a 15 kV circuit breaker to accommodate the addition of a 15 kV distribution feeder.

EDTI has advised that there is an existing spare 15 kV circuit breaker at the Rossdale substation, which can be used to connect a second 15 kV distribution feeder. As mentioned under the description of Alternative 1, there is an existing spare 15 kV circuit breaker at the Victoria substation, which can be used to connect a third 15 kV distribution feeder.

Alternative 3 – Modifications at the Victoria substation (one 15 kV circuit breaker)

Alternative 3 involves modifying the Victoria substation, including adding one 15 kV circuit breaker to accommodate the addition of one 15 kV distribution feeder.

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As mentioned above, there is an existing spare 15 kV circuit breaker at each of the Victoria and Rossdale substations, which can be used to connect two additional 15 kV distribution feeders.

Connection Alternative Selected for Further Study Alternative 1 is considered technically feasible and was selected for further study. Connection Alternatives Not Selected for Further Study Alternative 2 and Alternative 3 are considered technically feasible. The DFO has advised that these alternatives involve increased overall development and hence, increased costs compared to Alternative 1. Therefore, these alternatives were not selected for further study.

Results of Post-Project Studies The following is a brief summary of the post-Project studies results. The post-Project studies results, Project impact on the performance of the AIES, and applicable mitigation measures are shown in greater detail in Table E-1, below.

Category A conditions (N-G-0) No Reliability Criteria violations were observed under Category A conditions for any of the post- Project scenarios.

Category B contingency conditions (N-G-1) The post-Project power flow studies identified the same system performance issues under Category B contingency conditions that were identified in the pre-Project power flow studies. No new Reliability Criteria violations were observed.

Project Dependencies

No project dependencies were identified.

Conclusions and Recommendations Analysis and Conclusions Table E-1 provides analysis of, and conclusions about, the impact of the Project for selected contingencies, including mitigation measures for observed Reliability Criteria violations. The contingencies in Table E-1 were selected on the basis that Reliability Criteria violations were observed following those contingencies.

Table E-1: Project Impact and Mitigation Measures

Reliability Criteria Violations Occurrence Year/ Mitigation Measures (Pre-Project or Project Season (Pre-Project and Post-Project Impact Load Post-Project) Violation Contingency Scenarios) Pre: Real-time 902L Reduced 747L Pre-Project and operational practices (Sundance 310P – thermal 2017 SP (N. Calder - Genster) Post-Project Post: Real-time Wabamun 19S) loading operational practices

72RG1 72RG7 Pre-Project and Reduced 2017 SP Pre: Real-time

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Reliability Criteria Violations Occurrence Year/ Mitigation Measures (Pre-Project or Project Season (Pre-Project and Post-Project Impact Load Post-Project) Violation Contingency Scenarios)

(Rossdale - Garneau) (Rossdale - Garneau) Post-Project thermal operational practices loading Post: Real-time operational practices Pre: Real-time Reduced 72CH9 72CH11 Pre-Project and operational practices thermal 2017 SP (Clover Bar - Hardisty) (Clover Bar - Hardisty) Post-Project Post: Real-time loading operational practices Pre: Real-time Reduced 72CH11 72CH9 Pre-Project and operational practices thermal 2017 SP (Clover Bar - Hardisty) (Clover Bar - Hardisty) Post-Project Post: Real-time loading operational practices Pre: Real-time Reduced 72CK13 72CK12 Pre-Project and operational practices thermal 2017 SP (Clover Bar - Kennedale) (Clover Bar - Kennedale) Post-Project Post: Real-time loading operational practices Pre: Real-time Reduced 72CK12 72CK13 Pre-Project and operational practices thermal 2017 SP (Clover Bar - Kennedale) (Clover Bar - Kennedale) Post-Project Post: Real-time loading operational practices Pre: Real-time Reduced operational practices 72CH9 72CH11 Pre-Project and thermal 2017 WP (Clover Bar - Hardisty) (Clover Bar - Hardisty) Post-Project loading Post: Real-time operational practices

Pre: Real-time Reduced operational practices 72CH11 72CH9 Pre-Project and thermal 2017 WP (Clover Bar - Hardisty) (Clover Bar - Hardisty) Post-Project loading Post: Real-time operational practices

The connection assessment identified pre-Project and post-Project system performance issues under Category B contingency conditions. However, the connection assessment indicates that the Project will not adversely impact the performance of the AIES because the magnitude of each of the thermal criteria violations in the post-Project scenarios was lower than the corresponding thermal criteria violations observed in the pre-Project scenarios. Real-time operational practices are currently being used to manage the pre-Project system performance issues, and can be used to address the post-Project system performance issues. Based on the study results, Alternative 1 is technically viable. Recommendations It is recommended to proceed with the Project using Alternative 1 as the preferred option to respond to the DFO’s request for system access service. It is also recommended to continue to use real-time operational practices to manage the identified system performance issues.

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Contents

Executive Summary ...... 1 1. Introduction ...... 7 1.1. Project ...... 7 1.1.1. Overview ...... 7 1.1.2. Load Component ...... 7 1.1.3. Generation Component ...... 7 1.2. Study Scope ...... 7 1.2.1. Objectives ...... 7 1.2.2. Study Area ...... 8 1.2.3. Studies Performed ...... 11 1.3. Report Overview ...... 11 2. Criteria, System Data, and Study Assumptions ...... 11 2.1. Criteria, Standards, and Requirements ...... 11 2.1.1. AESO Reliability Criteria ...... 11 2.1.2. Authoritative Documents (ADs) ...... 12 2.2. Study Scenarios ...... 13 2.3. Load and Generation Assumptions ...... 13 2.3.1. Load Assumptions ...... 13 2.3.2. Generation Assumptions ...... 14 2.3.3. Intertie Flow and HVDC Assumptions ...... 14 2.4. System Projects ...... 14 2.5. Customer Connection Projects ...... 14 2.6. Facility Ratings and Shunt Elements ...... 15 2.7. Voltage Profile Assumptions ...... 18 3. Study Methodology ...... 19 3.1. Study Objectives ...... 19 3.2. Connection Studies Carried Out ...... 20 3.3. Power Flow Analysis ...... 20 3.3.1. Contingencies Studied for Power Flow Analysis ...... 20 3.4. Voltage Stability (PV) Analysis ...... 21 3.4.1. Contingencies Studied for Voltage Stability Analysis ...... 21 4. Pre-Project System Assessment ...... 21 4.1. Pre-Project Power Flow Studies ...... 21 4.1.1. Scenario 1 (2017 SP pre-Project) ...... 21 4.1.2. Scenario 2 (2017 WP pre-Project) ...... 23 5. Connection Alternatives ...... 24 5.1. Overview ...... 24 5.2. Connection Alternatives Examined ...... 24 5.2.1. Connection Alternatives Selected for Further Studies ...... 25 5.2.2. Connection Alternatives Not Selected for Further Studies ...... 25 6. Technical Analysis of Alternative 1 ...... 25 6.1. Power Flow Studies ...... 25 6.1.1. Scenario 3 (2017 SP post-Project) ...... 26 6.1.2. Scenario 4 (2017 WP post-Project) ...... 27 6.2. Voltage Stability Studies ...... 28 6.2.1. Scenario 3 (2017 SP post-Project) ...... 28 6.2.2. Scenario 4 (2017 WP post-Project) ...... 29 6.3. Results Summary ...... 29

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7. Project Dependencies ...... 31 8. Conclusions and Recommendations ...... 32

Attachments

Attachment A Pre-Project System Power Flow Plots Attachment B Post-Project Alternative 1: Power Flow Plots Attachment C Post-Project Alternative 1: Voltage Stability Analysis Plots

Figures

Figure 1-1: Study Area Transmission System ...... 9 Tables

Table 2-1: Post Contingency Voltage Deviations Guidelines for Low Voltage Busses ...... 12 Table 2-2: Study Scenarios and Assumptions ...... 13 Table 2-3: Forecast Area Load (2016 LTO at Edmonton Planning Region Peak) ...... 13 Table 2-4: Local Generators in the Study Scenarios ...... 14 Table 2-5: Customer Connection Projects in the Study Areaa ...... 15 Table 2-6: Main Transmission Lines in the Study Area (MVA on a 69/138/240 kV Base) ...... 16 Table 2-7: Summary of key transformer in the Study Area ...... 17 Table 2-8: Summary of Shunt Elements in the Study Area ...... 18 Table 2-9: Summary of the Voltage at Key Nodes in Study Scenarios ...... 19 Table 3-1: Summary of Studies Performed ...... 20 Table 4-1: Summary of pre-Project System Performance – Scenario 1 ...... 22 Table 4-2: Summary of pre-Project System Performance – Scenario 2 ...... 23 Table 5-1: Summary of examined transmission alternatives ...... 25 Table 6-1: Summary of post-Project System Performance – Scenario 3 ...... 27 Table 6-2: Summary of post-Project System Performance – Scenario 4 ...... 28 Table 6-3: Voltage stability analysis results – Scenario 3 (Minimum transfer = 100.4 MW) ...... 28 Table 6-4: Voltage stability analysis results – Scenario 4 (Minimum transfer = 98.55 MW) ...... 29 Table 6-5: Project Impact and Mitigation Measures ...... 29

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1. Introduction

This report details the engineering studies undertaken to assess the impact of the Project (as defined below) on the performance of the Alberta interconnected electric system (AIES).

1.1. Project

1.1.1. Overview EPCOR Distribution & Transmission Inc. (EDTI), in its capacity as the legal owner of an electric distribution system (DFO), submitted a system access service request to the Alberta Electric System Operator (AESO) to reliably serve new loads in downtown Edmonton. The DFO’s request for system access service includes a request for a Rate DTS, Demand Transmission Service, contract capacity increase of approximately 6 MW (from 133.92 MW to 140 MW) at the existing Victoria substation, and a request for transmission development (collectively, the Project). Specifically, the DFO requested modifications to the existing Victoria substation. The scheduled in-service date (ISD) for the Project is March 13, 2017.

1.1.2. Load Component The existing Rate DTS contract capacity for the system access service provided at the existing Victoria substation is 133.92 MW. The DFO requested a Rate DTS contract capacity increase of 6.08 MW. The Project load was studied assuming a 0.9 power factor (PF) lagging.

1.1.3. Generation Component There is no generation component associated with the Project.

1.2. Study Scope

1.2.1. Objectives The objectives of the studies were as follows:  Assess the impact of the Project on the performance of the AIES.  Identify any violations of the relevant AESO criteria, standards or requirements, both pre-Project and post-Project.  Recommend mitigation measures, if required, to reliably connect the Project to the AIES.

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1.2.2. Study Area

1.2.2.1. Study Area Description The Project is located in the AESO planning area of Edmonton (Area 60). Edmonton (Area 60) is surrounded by the planning areas of Fort Saskatchewan (Area 33), Athabasca/Lac La Biche (Area 27), Wabamun (Area 40), and Wetaskiwin (Area 31). From a transmission system perspective, Edmonton (Area 60) consists of 240 kV, 138/144 kV, and 69/72 kV transmission systems. The Victoria substation is connected to the Castle Downs substation by the 240 kV transmission line 240CV5, and is connected to the Rossdale substation by the 72 kV transmission lines 72RV4, 72RV6 and 72RV2. The Castle Downs substation connects to the North Calder 37S and Lamoureux 71S substations via the 240 kV transmission line 920L. The Victoria substation connects to the Argyll Transfer Station through the Bellamy substation. The Study Area for the Project consists of Edmonton (Area 60), including the tie lines connecting this planning area to neighbouring planning areas. All transmission facilities within the Study Area were studied and monitored to assess the impact of the Project on the performance of the AIES, including any violations of the Reliability Criteria (as defined in Section 2.1.1). The existing transmission system in the region is shown in Figure 1-1.

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Figure 1-1: Study Area Transmission System

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1.2.2.2. Existing Constraints Existing constraints in the Edmonton Planning Region are managed in accordance with the procedures set out in Section 302.1 of the ISO rules, Real Time Transmission Constraint Management (TCM Rule).

1.2.2.3. AESO Long-Term Transmission Plans The AESO 2015 Long-term Transmission Plan (2015 LTP)1 includes the following transmission developments that are in the vicinity of the Study Area in the near term (by 2020):2  Convert Hardisty substation in east Edmonton to 240/15 kV from 72/15 kV.  Add new 240 kV loop from Lambton substation in southeast Edmonton to Hardisty substation and onto Bellamy substation at Rossdale.  Discontinue use of 72 kV lines from Rossdale substation (Bellamy) to Strathcona substation to Lambton substation.  Replace existing 240/72 kV transformer at Clover Bar substation in northeast Edmonton with larger units.  Add new 240/72 kV substation near Namao in northeast, cut into 240 kV line between Castle Downs substation and Victoria substation on north edge of downtown Edmonton.  Add new 72 kV line from new substation to existing Namao substation  Add new 240/72 kV transformer at Castle Downs substation in the northeast  Add new 72 kV transmission lines from Castle Downs substation to Kennedale substation, and onto Namao substation  Discontinue use of 72 kV lines between Clover Bar and Hardisty substations, and Hardisty and Lambton substations  Discontinue use of existing 72 kV lines that connect Clover Bar, Victoria, Namao, Kennnedale, and Woodcroft substations  Convert Victoria substation from 240/72/15 kV to 240/15 kV  Add new 240 kV line from Victoria substation to Bellamy substation  Discontinue use of 72 kV lines between Rossdale and Victoria substations The above developments were not included in the system topology for the pre-Project and post-Project studies because these transmission developments are not expected to be in service before the Project ISD.

1 The 2015 LTP document is available on the AESO website. 2 The 2015 LTP identifies the near-term transmission developments in the City of Edmonton area on page 62.

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The Edmonton Region 240 kV Line Upgrades project is also progressing in the Edmonton Planning Region. This developments associated with this project were included in the topology for the connection assessment, as discussed in Section 2.4.3

1.2.3. Studies Performed The following studies were performed for the pre-Project scenarios:  Power flow studies (Category A conditions and Category B contingencies) The following studies were performed for the post-Project scenarios:  Power flow studies (Category A conditions and Category B contingencies)  Voltage stability studies (Category A conditions and Category B contingencies)

1.3. Report Overview

The Executive Summary provides a high-level summary of the report and its conclusions. Section 1 provides an introduction of the Project. Section 2 describes the criteria, system data, and study assumptions used in the studies. Section 3 presents the study methodology used in the studies. Section 4 discusses the pre-Project system assessment. Section 5 presents the connection alternatives that were examined and the alternatives that were studied. Section 6 presents the post-Project system assessment for the alternatives that were selected for further study. Section 7 identifies project dependencies, if any. Section 8 presents the conclusions and recommendations of this report.

2. Criteria, System Data, and Study Assumptions

2.1. Criteria, Standards, and Requirements

2.1.1. AESO Reliability Criteria The Transmission Planning (TPL) Standards, which are included in the Alberta Reliability Standards, and the AESO’s Transmission Planning Criteria – Basis and Assumptions4 (collectively, the Reliability Criteria) were applied to evaluate system performance under Category A system conditions (i.e., all elements in-service) and following Category B contingencies (i.e., single element outage), prior to and following the studied alternatives. Below is a summary of Category A and Category B system conditions.

3 The Edmonton Region 240 kV Line Upgrades Needs Identification Document (NID) was originally approved by the Alberta Utilities Commission in Approval No. U2009-62 on February 24, 2009. 4 Filed under a separate cover

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Category A, often referred to as the N-0 condition, represents a normal system with no contingencies and all facilities in service. Under this condition, the system must be able to supply all firm load and firm transfers to other areas. All equipment must operate within its applicable rating, voltages must be within their applicable range, and the system must be stable with no cascading outages. Category B events, often referred to as an N-1 or N-G-1 with the most critical generator out of service, result in the loss of any single specified system element under specified fault conditions with normal clearing. These elements include a generator, a transmission circuit, a transformer or a single pole of a DC transmission line. The acceptable impact on the system is the same as Category A. Planned or controlled interruptions of electric supply to radial customers or some local network customers, connected to or supplied by the faulted element or by the affected area, may occur in certain areas without impacting the overall reliability of the interconnected transmission systems. To prepare for the next contingency, system adjustments are permitted, including curtailments of contracted firm (non-recallable reserved) transmission service electric power transfers. The TPL standards, TPL-001-AB-0 and TPL-002-AB-0, have referenced Applicable Ratings when specifying the required system performance under Category A and Category B events. For the purpose of applying the TPL standards to the studies documented in this report, Applicable Ratings are defined as follows:  Seasonal continuous thermal rating of the line’s loading limits.  Highest specified loading limits for transformers.  For Category A conditions: Voltage range under normal operating condition per AESO Information Document # 2010-007RS (ID #2010-007RS). For the busses not listed in ID #2010-007RS, Table 2-1 in the Transmission Planning Criteria – Basis and Assumptions applies.  For Category B conditions: The extreme voltage range values per Table 2-1 in the Transmission Planning Criteria – Basis and Assumptions.  Desired post-contingency voltage change limits for three defined post event timeframes as provided in Table 2-1, below.

Table 2-1: Post Contingency Voltage Deviations Guidelines for Low Voltage Busses Time Period Parameter and reference point Post Transient Post Auto Control Post Manual Control (Up to 30 sec.) (30 sec. to 5 min.) (Steady State) Voltage deviation from steady state at low ± 10% ± 7% ± 5% voltage bus

2.1.2. Authoritative Documents (ADs) AESO ID #2010-007RS, General Operating Practices - Voltage Control, relates to Section 304.4 of the ISO rules, Maintaining Network Voltage. ID #2010-007RS was used to establish system normal (i.e., pre-contingency) voltage profiles for the Study Area.

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2.2. Study Scenarios

The scheduled ISD for the Project is March 13, 2017. Therefore, the studies were performed using the 2017 summer peak (SP) and 2017 winter peak (WP) scenarios. Table 2-2 provides a list of the study scenarios. Scenario 1 and Scenario 2 are the pre-Project 2017 SP and 2017 WP scenarios. Scenario 3 and Scenario 4 are the post-Project 2017 SP and 2017 WP scenarios. The post-Project scenarios reflect the requested Rate DTS contract capacity increase of 6.08 MW. A 0.9 PF lagging was used for the Project load.

Table 2-2: Study Scenarios and Assumptions

Scenario No. Year/Season Load Project Load (MW)

Pre-Project system

1 2017 SP 133.92

2 2017 WP 133.92

Post-Project system

3 2017 SP 140

4 2017 WP 140

2.3. Load and Generation Assumptions

2.3.1. Load Assumptions The load forecast used for the studies is shown in Table 2-3 and is based on the AESO 2016 Long-term Outlook (2016 LTO).

Table 2-3: Forecast Area Load (2016 LTO at Edmonton Planning Region Peak)

Area or Region Name and Year/Season Forecast Peak Load (MW)

Wetaskiwin 2017 SP 131 (Area 31) 2017 WP 140

Wabamun 2017 SP 179 (Area 40) 2017 WP 197

Edmonton 2017 SP 2,008 (Area 60) 2017 WP 1,971

Edmonton Planning 2017 SP 2,318 Region 2017 WP 2,308

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Area or Region Name and Year/Season Forecast Peak Load (MW)

Alberta Internal Load 2017 SP 10,941 (AIL) w/o Losses 2017 WP 11,900

2.3.2. Generation Assumptions The generation assumptions for the studies are described in Table 2-4. The Cloverbar #3 generating unit was identified as the critical generating unit, and was considered to be out of service to represent the N-G condition for all studies.

Table 2-4: Local Generators in the Study Scenarios 2017 SP 2017 WP Bus Pmax Existing/Future Unit Name Area Unit Net Unit Net Number (MW) Generation Generation (MW) (MW) Existing Cloverbar #1 25516 60 48 0 0 Existing Cloverbar #2 26516 60 101 42 73 Existing Cloverbar #3 27516 60 101 Offline Offline Existing University of Alberta 25352 60 39 9 27

2.3.3. Intertie Flow and HVDC Assumptions The Alberta-BC, Alberta-Montana, and Alberta-Saskatchewan intertie points were deemed to be too far away from the Study Area to have any material effect on the assessment of the Project’s impact on the performance of the AIES. Therefore, the intertie flows were assumed to be the same as in the AESO planning base cases and were not adjusted for the studies. The Western Alberta Transmission Line (WATL) and the Eastern Alberta Transmission Line (EATL) assumptions were expected to have minimal effects on the assessment of the Project’s impact on the performance of the AIES. Therefore, the HVDC assumptions were assumed to be the same as in the AESO planning base cases and were not adjusted for the studies.

2.4. System Projects

Project 786 (Edmonton Region 240 kV Line Upgrades), which has an ISD of November 30, 2016, was modeled in the study scenarios.

2.5. Customer Connection Projects

Customer connection projects within the Study Area that have passed Gate 2 of the AESO Connection Process as of November 2016 were modelled in the study scenarios based on their positions in the AESO Connection Queue. Table 2-5 summarizes the customer connection

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Table 2-5: Customer Connection Projects in the Study Areaa

Modelled in Planning Queue Project Project Description Planned ISD the study Area Position* Number cases Genesee Generating Units 4 (G4) 60 42 1440 Q1- 2019 Noc and 5 (G5)

Fortis New Anthony Henday b 60 36 1442 Q1- 2019 No Substation

60 84 1649 EPCOR Garneau Area Upgrade Q4- 2018 Noc

EPCOR Strathcona Capacity b 60 91 1659 Q4- 2018 No Increase

Fortis Cooking Lake 522A Capacity 60 77 1674 Q1- 2018 Yes Increase

Notes: a Per the AESO Connection Queue posted in November 2016. The projects in the Study Area, if any, that have queue positions after Project 1711 are not listed in this table and were not modelled in the study cases. b This project is deemed to be too far away from the Project to have any material effect on the assessment of the Project’s impact on the performance of the AIES. c Including these projects in the customer connection assumptions would result in less stressed study cases for this connection assessment. Therefore, for the purpose of assessing the impact of the Project on the performance of the AIES, these projects were not included in the customer connection project assumptions.

2.6. Facility Ratings and Shunt Elements

The legal owner of transmission facilities (TFO) provided the seasonal continuous thermal ratings and the short-term emergency ratings for the transmission lines in the Study Area. The seasonal continuous thermal ratings and the short-term emergency ratings for the main transmission lines in the Study Area are shown in Table 2-6.

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Table 2-6: Main Transmission Lines in the Study Area (MVA on a 69/138/240 kV Base) Line Ratings

Line Description Seasonal Voltage Short-term (Substation) Continuous Line ID Class Emergency Ratings Thermal Ratings (kV) 5 (MVA) (MVA)

From To Summer Winter Summer Winter

Lamoureux 240 921L Clover Bar 417 499 500 620 71S

East 240 915L Clover Bar Edmonton 492 499 590 648 38S

947L Clover Bar Ellerslie 89S 240 493 611 592 733

240CV5 Victoria Castle Downs 240 475 503 475 503

908AL 240 908AL East Industrial 587 754 704 905 tap point

1057L Summerside Ellerslie 89S 240 594 713 654 773

908L Petrolia Ellerslie 89S 240 505 648 606 773

Keephills 240 909L Dome 481 581 577 697 320P

909L Ellerslie 89S Dome 240 499 599 599 648

1059L 240 1059L Lambton 499 499 694 853 tap point

1058L Lambton Summerside 240 499 499 694 853

East 240 908AL 908L Edmonton 499 499 599 648 tap point 38S

East 240 1059AL tap 1059L Edmonton 499 499 599 648 point 38S

1056L Ellerslie 89S Argyll 240 419 517 503 620

1055L Petrolia Argyll 240 419 517 503 620

240BA2 Argyll Bellamy 240 400 479 400 479

240BA3 Argyll Bellamy 240 400 479 400 479

908AL 240 908L Ellerslie 89S 505 648 606 773 tap point

1044L Petrolia Jasper 240 481 581 577 697

1045L Jasper Sundance 240 481 581 577 697

5 Ratings for the 72 kV transmission lines are provided on the system base voltage of 69 kV.

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Line Ratings

Line Description Seasonal Voltage Short-term (Substation) Continuous Line ID Class Emergency Ratings Thermal Ratings (kV) 5 (MVA) (MVA)

From To Summer Winter Summer Winter 310P

72RS5 Rossdale Strathcona 69 23.9 23.9 67.4 70.3

72LH8 Lambton Hardisty 69 86.3 118.8 101.0 129.7

72LS24 Lambton Strathcona 69 86.2 118.8 101.0 129.7

72JM18 Meadowlark Jasper 69 57.5 62.3 57.5 62.3

72JW19 Jasper Woodcroft 69 57.5 62.3 57.5 62.3

72RW3 Woodcroft Rossdale 69 57.0 62.0 57.0 62.0

72RG7 Garneau Rossdale 69 76.0 86.0 76.0 86.0

72RV2 Victoria Rossdale 69 63.9 63.9 63.9 63.9

72RG1 Garneau Rossdale 69 57.0 62.0 57.0 62.0

72RV4 Victoria Rossdale 69 63.9 63.9 63.9 63.9

72RV6 Victoria Rossdale 69 63.9 63.9 63.9 63.9

72VN21 Victoria Namao 69 57.5 62.3 57.5 62.3

72CH11 Clover Bar Hardisty 69 38.0 38.0 77.0 77.0

72CH9 Clover Bar Hardisty 69 38.0 38.0 77.0 77.0

72NW15 Woodcroft Namao 69 61.3 85.3 71.7 92.6

72NK23 Namao Kennedale 69 57.0 57.0 57.0 57.0

72CN10 Namao Clover Bar 69 57.5 57.5 57.5 57.5

72CK12 Kennedale Clover Bar 69 46.0 53.6 61.0 65.0

72CK13 Kennedale Clover Bar 69 46.0 53.6 61.0 65.0

The TFO also provided the details of the substation transformer elements in the Study Area. The key transformers in the Study Area are shown in Table 2-7.

Table 2-7: Summary of key transformer in the Study Area

Station Name and Number Transformer MVA Rating

T5 – 240/72 kV 450

T1 – 72/14.4 kV 66.7 Victoria T2 – 72/14.4 kV 66.7

T3 – 72/14.4 kV 66.7

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T4 – 72/14.4 kV 66.7

Jasper T1 – 240/72 kV 300

Lambton T3 – 240/72 kV 80

T1 – 240/72 kV 375 Bellamy T2 – 240/72 kV 375

The TFO also provided the details of the shunt elements in the Study Area, as shown in Table 2-8. No shunt reactors are present in the Study Area. Table 2-8: Summary of Shunt Elements in the Study Area

Capacitor Station Name and Number Voltage Class (kV) (MVAr)

East Edmonton 38S 138 2 x 48.91

Nisku 149S 138 1 x 30

Acheson 305S 138 1 x 24.46

Jasper 240 1 x 105.31

Rossdale 69 2 x 47.75

Clover Bar 69 1 x 31.57

Stelco Edmonton 133S 34.5 2 x 23.4

2.7. Voltage Profile Assumptions

The AESO ID #2010-007RS was used to establish system normal (i.e., pre-contingency) voltage profiles for key area busses prior to commencing any studies. Table 2-1 of the Transmission Planning Criteria – Basis and Assumptions applies for all the busses not included in ID #2010-007RS. These voltages were used to set the voltage profile for the study base cases prior to performing the power flow studies. The key bus voltages for the Study Area for the Project are shown in Table 2-9.

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Table 2-9: Summary of the Voltage at Key Nodes in Study Scenarios

Voltage in the Study Cases ID #2010-007RS under Category A conditions (kV) Substation Nominal Name and Voltage Minimum Maximum Pre-Project Post-Project Number (kV) Operating Desired Operating Limit Range (kV) Limit 2017 SP 2017 WP 2017 SP 2017 WP (kV) (kV)

East 240 240 240-253 255 246.09 250.79 246.54 250.8 Edmonton 38S 138 139 139-144 145 140.01 141.43 140.1 141.45

6 Bigstone 240 Left Blank 243-253 260 244.65 249.01 246.32 249.02 86S 138 135 141-145 145 144.44 143.00 142.81 143.02

Acheson 138 138 138-144 145 138.75 140.00 138.17 140.04 305S

500 505 520-540 550 533.62 539.14 534.31 539.15 Ellerslie 89S 240 243 246-254 255 247.71 252.03 248.23 252.03

Petrolia 240 240 245-254 255 247.96 252.32 248.53 252.31

Clover Bar 240 240 245-254 255 246.64 251.07 247.08 251.08

Lambton 240 240 245-254 255 246.00 250.71 246.48 250.72

Bellamy 240 Left Blank7 Left Blank8 255 247.44 252.31 247.99 252.3

Jasper 240 240 245-254 255 247.87 252.23 248.73 252.23

3. Study Methodology

The studies for this connection assessment were completed using PTI PSS/E version 33.

3.1. Study Objectives

The objectives of the studies were as follows:  Assess the impact of the Project on the performance of the AIES.  Identify any violations of the relevant AESO criteria, standards or requirements, both pre-Project and post-Project.  Recommend mitigation measures, if required, to reliably connect the Project to the AIES.

6 This value was intentionally left blank, per ID #2010-007RS. 7 This value was intentionally left blank, per ID #2010-007RS. 8 This value was intentionally left blank, per ID #2010-007RS.

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3.2. Connection Studies Carried Out

The following studies were performed for the pre-Project scenarios:  Power flow studies (Category A conditions and Category B contingencies) The following studies were performed for the post-Project scenarios:  Power flow studies (Category A conditions and Category B contingencies)  Voltage stability studies (Category A conditions and Category B contingencies) Table 3-1 summarizes the studies that were carried out for this connection assessment. Table 3-1: Summary of Studies Performed Scenario(s) Studied Studies Performed System Conditions Studied Pre-Project Post-Project 1, 2 3, 4 Power flow Category A and Category B

- 3, 4 Voltage stability Category A and Category B

3.3. Power Flow Analysis

Pre-Project and post-Project power flow studies were performed to identify thermal and voltage criteria violations as per the Reliability Criteria, and any deviations from the limits listed in Table 2-1. The purpose of the power flow analysis is to quantify any incremental violations in the Study Area after the Project is connected. For the Category B power flow studies, the transformer taps and switched shunt reactive compensating devices such as shunt capacitors and reactors were locked and continuous shunt devices were enabled. Point-of-delivery (POD) low voltage bus deviations were assessed for both the pre-Project and post-Project networks by first locking all tap changers and area shunt reactive compensating devices to identify any post transient voltage deviations above 10%. Second, tap changers were allowed to move while shunt reactive compensating devices remained locked to determine if any voltage deviations above 7% would occur in the area. Third, all the taps and shunt reactive compensating devices were allowed to adjust, and voltage deviations above 5% would be reported.

3.3.1. Contingencies Studied for Power Flow Analysis The power flow studies included all Category B contingencies (69 kV facilities and above) within the Study Area. All transmission facilities in the Study Area were monitored for voltage criteria violations and thermal criteria violations under Category A conditions and under Category B contingency conditions.

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3.4. Voltage Stability (PV) Analysis

The objective of the voltage stability analysis is to determine the ability of the network to maintain voltage stability at all the busses in the system under normal and abnormal system conditions. The power-voltage (PV) curve represents voltage change as a result of increased power transfer between two systems. The reported incremental transfers are to the collapse point. As per the AESO requirements, no assessment based upon other criteria such as minimum voltage were made at the PV minimum transfer. Voltage stability analyses were performed for post-Project scenarios. For load connection projects, the load level modelled in post-Project scenarios is the same or higher than in pre- Project scenarios. Therefore, voltage stability analysis for pre-Project scenarios would only be performed if the post-Project scenarios show voltage stability criteria violations. The voltage stability analyses followed the Western Electricity Coordinating Council (WECC) Voltage Stability Assessment Methodology. WECC voltage stability criteria states, for load areas, post-transient voltage stability is required for the area modeled at a minimum of 105% of the reference load level for system normal conditions (Category A) and for single contingencies (Category B). For this standard, the reference load level is the maximum established planned load. Typically, voltage stability analysis is carried out assuming worst case loading scenarios. For the Project’s worst case scenario, load was increased in Edmonton (Area 60) and corresponding generation was increased in Fort McMurray (Area 25).

3.4.1. Contingencies Studied for Voltage Stability Analysis The voltage stability analyses were performed for the Category A condition and all Category B contingencies (69 kV facilities and above) in the Study Area to determine the system voltage stability margin in the area.

4. Pre-Project System Assessment

This section provides the results of the pre-Project power flow studies and includes the mitigation measures for observed Reliability Criteria violations, if any.

4.1. Pre-Project Power Flow Studies

The pre-Project power flow diagrams are provided in Attachment A.

4.1.1. Scenario 1 (2017 SP pre-Project) Category A conditions (N-G-0) No Reliability Criteria violations were observed under Category A conditions. Category B contingency conditions (N-G-1)

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No voltage criteria violations were observed under Category B contingency conditions. Thermal criteria violations were observed under Category B contingency conditions. The thermal criteria violations and the applicable mitigation measures, which are also described below, are shown in Table 4-1.  Loading above the short-term emergency rating of the 72 kV transmission line 72RG1 (between the Rossdale and Garneau substations) was observed following the loss of the 72 kV transmission line 72RG7 (between the Rossdale and Garneau substations).  Loading above the short-term emergency rating of the 138 kV transmission line 747L (between the North Calder and Genster substations) was observed following the loss of the 240 kV transmission line 902L (between the Sundance 310P and Wabamun 19S substations).  Loading below the short-term emergency rating of the 72 kV transmission line 72CH9 (between the Clover Bar and Hardisty substations) was observed following the loss of the 72 kV transmission line 72CH11 (between the Clover Bar and Hardisty substations).  Loading below the short-term emergency rating of the 72 kV transmission line 72CH11 was observed following the loss of the 72 kV transmission line 72CH9.  Loading below the short-term emergency rating of the 72 kV transmission line 72CK13 (between the Clover Bar and Kennedale substations) was observed following the loss of the 72 kV transmission line 72CK12 (between the Clover Bar and Kennedale substations).  Loading below the short-term emergency rating of the 72 kV transmission line 72CK12 was observed following the loss of the 72 kV transmission line 72CK13. These thermal criteria violations are currently being managed by using real-time operational practices.

Table 4-1: Summary of pre-Project System Performance – Scenario 1

Details of Reliability Line Ratings Criteria Violations

Mitigation Contingency Limiting Facilities Seasonal Short-term Measures Continuous Emergency Load Flow % Thermal Rating (MVA) Loading Rating (MVA) (MVA)

Real-time 72RG7 72RG1 57 57 69.6 122.1 operational (Rossdale - Garneau) (Rossdale - Garneau) practices Real-time 72CH11 72CH9 38 77 60.6 159.5 operational (Clover Bar - Hardisty) (Clover Bar - Hardisty) practices

72CH9 72CH11 38 77 60.6 159.5 Real-time

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(Clover Bar - Hardisty) (Clover Bar - Hardisty) operational practices Real-time 72CK12 72CK13 46 61 54.9 119.3 operational (Clover Bar - Kennedale) (Clover Bar - Kennedale) practices Real-time 72CK13 72CK12 46 61 54.9 119.3 operational (Clover Bar - Kennedale) (Clover Bar - Kennedale) practices

902L Real-time 747L (Sundance 310P – 119 131 136.14 114.4 operational (N. Calder - Genster) Wabamun 19S) practices

4.1.2. Scenario 2 (2017 WP pre-Project) Category A conditions (N-G-0) No Reliability Criteria violations were observed under Category A conditions. Category B contingency conditions (N-G-1) No voltage criteria violations were observed under Category B contingency conditions. Thermal criteria violations were observed under Category B contingency conditions. The thermal criteria violations and the applicable mitigation measures, which are also described below, are shown in Table 4-2.  Loading below the short-term emergency rating of the 72 kV transmission line 72CH9 was observed following the loss of the 72 kV transmission line 72CH11.  Loading below the short-term emergency rating of the 72 kV transmission line 72CH11 was observed following the loss of the 72 kV transmission line 72CH9. These thermal criteria violations are currently being managed by using real-time operational practices. Table 4-2: Summary of pre-Project System Performance – Scenario 2

Details of Reliability Line Ratings Criteria Violations Mitigation Contingency Limiting Facilities Short-term Seasonal Load Measures Emergency % Continuous Flow Rating Loading Thermal Rating (MVA) (MVA) (MVA) 72CH11 72CH9 Real-time (Clover Bar - (Clover Bar - 38 77 59.3 156.1 operational Hardisty) Hardisty) practices

72CH9 72CH11 Real-time (Clover Bar - (Clover Bar - 38 77 59.3 156.1 operational Hardisty) Hardisty) practices

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5. Connection Alternatives

5.1. Overview

The AESO, in consultation with the DFO and the TFO, examined three transmission alternatives to meet the DFO’s request for system access service.9

5.2. Connection Alternatives Examined

Below is a description of the developments associated with the transmission alternatives that were examined for the Project. Each of the transmission alternatives involves the addition of two 15 kV distribution feeders to serve the new loads and a third 15 kV distribution feeder to provide standby capability. Table 5-1 also summarizes the transmission alternatives.

Alternative 1 – Modifications at the Victoria substation (two 15 kV circuit breakers)

Alternative 1 involves modifying the existing Victoria substation, including adding two 15 kV circuit breakers to accommodate the addition of two 15 kV distribution feeders.

EDTI has advised that there is an existing spare 15 kV circuit breaker at the Victoria substation, which can be used to connect a third 15 kV distribution feeder.

Alternative 2 – Modifications at the Rossdale substation

Alternative 2 involves modifying the existing Rossdale substation, including adding a 15 kV circuit breaker to accommodate the addition of a 15 kV distribution feeder.

EDTI has advised that there is an existing spare 15 kV circuit breaker at the Rossdale substation, which can be used to connect a second 15 kV distribution feeder. As mentioned under the description of Alternative 1, there is an existing spare 15 kV circuit breaker at the Victoria substation, which can be used to connect a third 15 kV distribution feeder.

Alternative 3 – Modifications at the Victoria substation (one 15 kV circuit breaker)

Alternative 3 involves modifying the Victoria substation, including adding one 15 kV circuit breaker to accommodate the addition of one 15 kV distribution feeder.

As mentioned above, there is an existing spare 15 kV circuit breaker at each of the Victoria and Rossdale substations, which can be used to connect two additional 15 kV distribution feeders.

9 These alternatives reflect more up to date engineering design than the alternatives identified in EPCOR Distribution & Transmission Inc.’s Distribution Deficiency Report (DDR), Victoria Substation (E511S) Breaker Additions, which is filed under a separate cover.

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Table 5-1: Summary of examined transmission alternatives

Alternative no. Alternative 1 Alternative 2 Alternative 3

Rossdale and Rossdale and Substation(s) involved Victoria Victoria Victoria

Existing spare circuit breakers 1 x 15 kV (Victoria) 1 x 15 kV (Victoria) 1 x 15 kV (Victoria) involved 1 x 15 kV (Rossdale) 1 x 15 kV (Rossdale)

Additional circuit breakers involved 2 x 15 kV (Victoria) 1 x 15 kV (Rossdale) 1 x 15 kV (Victoria)

a a Distribution feeder length, approx. 5 km (Rossdale ) 2.5 km (Rossdale ) 3 km (Victoria) (From substation to load centre(s)) 1 km (Victoria) 2 km (Victoria)

Total distribution feeder length, 3 km 6 km 4.5 km approx.

Notes: a Additional costs due to complexity associated with routing the distribution feeders across 102 Avenue

5.2.1. Connection Alternatives Selected for Further Studies Alternative 1 is considered technically feasible and was selected for further study.

5.2.2. Connection Alternatives Not Selected for Further Studies Alternative 2 and Alternative 3 are considered technically feasible. The DFO has advised that these alternatives involve increased overall development and hence, increased costs compared to Alternative 1. Therefore, these alternatives were not selected for further study.

6. Technical Analysis of Alternative 1

This section provides the analysis of the post-Project power flow and voltage stability studies and includes the study results and the mitigation measures for observed Reliability Criteria violations, if any.

6.1. Power Flow Studies

The post-Project power flow diagrams are provided in Attachment B.

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6.1.1. Scenario 3 (2017 SP post-Project) Category A conditions (N-G-0) No Reliability Criteria violations were observed under Category A conditions. Category B contingency conditions (N-G-1) No voltage criteria violations were observed under Category B contingency conditions. Thermal criteria violations were observed under Category B contingency conditions. The thermal criteria violations and the applicable mitigation measures, which are also described below, are shown in Table 6-1. All of these post-Project system performance issues were identified in the pre-Project Scenario 1 (2017 SP). However, the magnitude of each of the violations in the post-Project Scenario 3 was lower than the corresponding thermal criteria violations observed in the pre-Project Scenario 1.  Loading above the short-term emergency rating of the 72 kV transmission line 72RG1 was observed following the loss of the 72 kV transmission line 72RG7.  Loading above the short-term emergency rating of the 138 kV transmission line 747L was observed following the loss of the 240 kV transmission line 902L.  Loading below the short-term emergency rating of the 72 kV transmission line 72CH9 was observed following the loss of the 72 kV transmission line 72CH11.  Loading below the short-term emergency rating of the 72 kV transmission line 72CH11 was observed following the loss of the 72 kV transmission line 72CH9.  Loading below the short-term emergency rating of the 72 kV transmission line 72CK13 was observed following the loss of the 72 kV transmission line 72CK12.  Loading below the short-term emergency rating of the 72 kV transmission line 72CK12 was observed following the loss of the 72 kV transmission line 72CK13. These thermal criteria violations can be managed by using real-time operational practices.

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Table 6-1: Summary of post-Project System Performance – Scenario 3

Details and Comparison of Reliability Criteria Violations Difference Line Ratings % Loading Pre-Project Post-Project Mitigation Between Limiting (Scenario 1) (Scenario 3) Measures Contingency Pre- Facilities (Post- Project Seasonal Short-term Project) Load Load and Post- Continuous Emergency % % Flow Flow Project Thermal Rating Loading Loading (MVA) (MVA) Scenarios Rating (MVA) (MVA) 72RG7 72RG1 Real-time (Rossdale - (Rossdale - 57 57 69.6 122.1 69.1 121.2 -0.9 operational Garneau) Garneau) practices

72CH11 72CH9 Real-time (Clover Bar - (Clover Bar to 38 77 60.6 159.5 60.3 158.7 -0.8 operational Hardisty) Hardisty) practices

72CH9 72CH11 Real-time (Clover Bar - (Clover Bar - 38 77 60.6 159.5 60.3 158.7 -0.8 operational Hardisty) Hardisty) practices

72CK12 72CK13 Real-time (Clover Bar - (Clover Bar - 46 61 54.9 119.3 54.6 118.7 -0.7 operational Kennedale) Kennedale) practices

72CK13 72CK12 Real-time (Clover Bar - (Clover Bar - 46 61 54.9 119.3 54.6 118.7 -0.7 operational Kennedale) Kennedale) practices

902L (Sundance 747L Real-time 310P - (N. Calder to 119 131 136.14 114.4 131.38 110.4 -4.0 operational Wabamun Genster) practices 19S)

6.1.2. Scenario 4 (2017 WP post-Project) Category A conditions (N-G-0) No Reliability Criteria violations were observed under Category A conditions. Category B contingency conditions (N-G-1) No voltage criteria violations were observed under Category B contingency conditions. Thermal criteria violations were observed under Category B contingency conditions. The thermal criteria violations and the applicable mitigation measures, which are also described below, are shown in Table 6-2. All of these post-Project system performance issues were identified in the pre-Project Scenario 2 (2017 WP). However, the magnitude of each of the violations in the post-Project Scenario 4 was lower than the corresponding thermal criteria violations observed in the pre-Project Scenario 2.  Loading below the short-term emergency rating of the 72 kV transmission line 72CH9 was observed following the loss of the 72 kV transmission line 72CH11.  Loading below the short-term emergency rating of the 72 kV transmission line 72CH11 was observed following the loss of the 72 kV transmission line 72CH9.

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These thermal criteria violations can be managed by using real-time operational practices. Table 6-2: Summary of post-Project System Performance – Scenario 4

Details and Comparison of Reliability Criteria Violations Difference Line Ratings % Pre-Project Post-Project Loading Mitigation Limiting (Scenario 2) (Scenario 4) Between Measures Contingency Facilities Pre-Project (Post- Seasonal Short-term and Post- Project Load Load Continuous Emergency % % Project Flow Flow Thermal Rating Loading Loading Scenarios (MVA) (MVA) Rating (MVA) (MVA) 72CH9 72CH11 Real-time (Clover (Clover Bar - 38 77 59.3 156.1 59.09 155.5 -0.6 operational Bar - Hardisty) practices Hardisty)

72CH11 72CH9 Real-time (Clover (Clover Bar - 38 77 59.3 156.1 59.09 155.5 -0.6 operational Bar - Hardisty) practices Hardisty)

6.2. Voltage Stability Studies

The voltage stability diagrams are provided in Attachment C.

6.2.1. Scenario 3 (2017 SP post-Project) For Scenario 3, the reference load level for the Study Area is 2,008 MW. For Category B contingencies, the minimum incremental load transfer to meet the 105% load criterion is 5.0% of the reference load, or 100.4 MW (0.05 x 2,008 MW = 100.4 MW). Table 6-3 provides the voltage stability studies results under Category A conditions and for the five worst contingencies under Category B conditions. The voltage stability margin was met for all studied conditions.

Table 6-3: Voltage stability analysis results – Scenario 3 (Minimum transfer = 100.4 MW)

Maximum Meets 105% Contingency From To incremental transfer transfer criteria? (MW)

N-G-0 System normal 331.25 Yes

Category B (Minimum Transfer = 100.4 MW)

Transformer T2 at the Clover Bar Clover Bar 315.63 Yes Clover Bar substation bus 514 bus 516

240 kV transmission Castle Downs Victoria 315.63 Yes line 240CV5 bus 519 bus 520

Transformer T5 at the Victoria Victoria 315.63 Yes Victoria substation bus 520 bus 533

Transformer T1 at the Clover Bar Clover Bar 315.63 Yes Clover Bar substation bus 514 bus 516

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Maximum Meets 105% Contingency From To incremental transfer transfer criteria? (MW)

240 kV transmission Wabamun 19S Sundance 310P 323.44 Yes line 902L bus 133 532 bus 135 542

6.2.2. Scenario 4 (2017 WP post-Project) For Scenario 4, the reference load level for the Study Area is 1,971 MW. For Category B contingencies, the minimum incremental load transfer to meet the 105% load criterion is 5.0% of the reference load, or 98.55 MW (0.05 x 1,890 MW = 98.55 MW). Table 6-4 provides the voltage stability studies results under Category A conditions and for the five worst contingencies under Category B conditions. The voltage stability margin was met for all studied conditions.

Table 6-4: Voltage stability analysis results – Scenario 4 (Minimum transfer = 98.55 MW)

Maximum Meets 105% Contingency From To incremental transfer transfer criteria? (MW)

N-G-0 System normal 312.5 Yes

Category B (Minimum Transfer = 100.4 MW)

Transformer T2 at the Clover Bar Clover Bar 312.5 Yes Clover Bar substation bus 514 bus 516

240 kV transmission Castle Downs Victoria 300 Yes line 240CV5 bus 519 bus 520

Transformer T5 at the Victoria Victoria 300 Yes Victoria substation bus 520 bus 533

Transformer T1 at the Clover Bar Clover Bar 312.5 Yes Clover Bar substation bus 514 bus 516

240 kV transmission Wabamun 19S Sundance 310P 312.5 Yes line 902L bus 133 532 bus 135 542

6.3. Results Summary

The Reliability Criteria violations observed during the connection assessment studies are summarized in Table 6-5. Table 6-5: Project Impact and Mitigation Measures

Reliability Criteria Violations Occurrence Year/ Mitigation Measures (Pre-Project or Project Season (Pre-Project and Post-Project Impact Load Post-Project) Violation Contingency Scenarios) Pre: Real-time 902L Reduced 747L Pre-Project and operational practices (Sundance 310P – thermal 2017 SP (N. Calder - Genster) Post-Project Post: Real-time Wabamun 19S) loading operational practices 72RG1 72RG7 Pre: Real-time 2017 SP (Rossdale - Garneau) (Rossdale - Garneau) Pre-Project and Reduced operational practices

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Reliability Criteria Violations Occurrence Year/ Mitigation Measures (Pre-Project or Project Season (Pre-Project and Post-Project Impact Load Post-Project) Violation Contingency Scenarios)

Post-Project thermal Post: Real-time loading operational practices Pre: Real-time Reduced 72CH9 72CH11 Pre-Project and operational practices thermal 2017 SP (Clover Bar - Hardisty) (Clover Bar - Hardisty) Post-Project Post: Real-time loading operational practices Pre: Real-time Reduced 72CH11 72CH9 Pre-Project and operational practices thermal 2017 SP (Clover Bar - Hardisty) (Clover Bar - Hardisty) Post-Project Post: Real-time loading operational practices Pre: Real-time Reduced 72CK13 72CK12 Pre-Project and operational practices thermal 2017 SP (Clover Bar - Kennedale) (Clover Bar - Kennedale) Post-Project Post: Real-time loading operational practices Pre: Real-time Reduced 72CK12 72CK13 Pre-Project and operational practices thermal 2017 SP (Clover Bar - Kennedale) (Clover Bar - Kennedale) Post-Project Post: Real-time loading operational practices

Pre: Real-time Reduced operational practices 72CH9 72CH11 Pre-Project and thermal 2017 WP (Clover Bar - Hardisty) (Clover Bar - Hardisty) Post-Project loading Post: Real-time operational practices

Pre: Real-time Reduced operational practices 72CH11 72CH9 Pre-Project and thermal 2017 WP (Clover Bar - Hardisty) (Clover Bar - Hardisty) Post-Project loading Post: Real-time operational practices

The power flow studies results identified pre-Project and post-Project system performance issues under Category B contingency conditions. However, the connection assessment indicates that the Project will not adversely impact the performance of the AIES because the magnitude of each of the thermal criteria violations in the post-Project scenarios was lower than the corresponding thermal criteria violations observed in the pre-Project scenarios. Real-time operational practices are currently being used to manage the pre-Project system performance issues, and can be used to address the post-Project system performance issues. The post-Project voltage stability analyses confirm that the voltage stability margin of the Study Area was met under all studied conditions. Based on the study results, Alternative 1 is technically viable.

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7. Project Dependencies

The Project is not dependent on the AESO’s plans to expand or enhance the transmission system.

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8. Conclusions and Recommendations

Based on the study results, Alternative 1 is technically viable. The connection assessment identified a number of pre-Project and post-Project system performance issues. However, the connection assessment indicates that the Project will not adversely impact the performance of the AIES because the magnitude of each of the thermal criteria violations in the post-Project scenarios was lower than the corresponding thermal criteria violations observed in the pre- Project scenarios. Real-time operational practices are currently being used to manage the pre-Project system performance issues, and can be used to address the post-Project system performance issues. It is recommended to proceed with the Project using Alternative 1 as the preferred option to respond to the DFO’s request for system access service. It is also recommended to continue to use real-time operational practices to manage the identified system performance issues.

32 November 2016 Attachment A

Pre-Project Power Flow Diagrams (Scenarios 1 and 2)

November 2016 247.84 57 246.28 519 -9.05 6.66 LAMOURE4 26.00 28.83 7.95 111.96 37.83 -8.93 34.16 CASTLEDN 549 143.59 63 141.26 82.25 16.88 INLANDCT LAMOURE7-11.82 -10.37 162.64 72.39 530 -9.66 516 NAMAO 8 CLOVERB8 36.49 21.09 27.50 27.51 28.91 27.66 59.91 57.14

520 246.22 28.72 27.45 514 246.64 VICTORIA -9.10 CLOVERB4 -7.90 113.05 26.39 81.21 16.67 59.50 56.71 533 72VN21 528 366 143.28 VICTORIA KENNDALE 898 143.80 VISCOUNT -11.99 GENSTR T -11.71 72CN10 57.05 93.81 32.51 27.49 27.46 56.73 27.60 57.68 28.06 81.21 17.59 45.64 43.33 164.71 1 0.9783 27.11 1 9 2 9 2 76.25 71.64 . . 44.56 50.44 0 8 8 9 95.79 80.63 71.84 25337 58.01 25331

-9.95 VIC 1 0.98226 1 VIC R1 27.56 1

59.03 54.61 54.61 54.605398.02 71.49 29.12 80.25 WOODCRF2 -11.48 85.26 81.00 54.02 54.02 3.90 72.83 0.98226 1 2 17.18 2 940 143.82 25335 . 9 9 N CALDE7. 0 -11.69 28.76 0 VIC R3 136 246.09 7 35.13 19.95 44.65 50.35 14.55 71.91 E EDMON4 -7.68

18.17 17.82 58.20 94.33 18.69 18.55 -49.46 72.61

73.25 44.07 44.07 24.10

218.93 -9.55 357 141.48 25333 STALBE7 -12.87 30.24 VIC R3C 40.98 35.27 70.68 13.82 94.58 80.92 535 71.64 207.49 1 GARNEAU8 -11.42 43.74 14.55 180.39 38.13 36.33 36.33 36.33 -49.46 502 55.07 52.86 88.14 88.14 HARDIST8 72CH11 72CH9 0.95 33.20 55.61 39.28 49.13 25338 31.18 785 246.00 31.27 VIC 2 14.84 78.49 1059A_TP -7.60 45.23 -46.73 71.03 13.89 18.17 17.82 9.50 31.52 227.16 77.21 162.86 37.89 25332 44.07 44.07 3.90 79.34 VIC R2 94.66 15.98 246.19 137 14.84 -46.74

-8.35 59.27 N CALDE4 36.97 22.90 181.71 182.38 59.41 54.96 54.96 54.95 58.20 33.13 85.81 81.52 81.16 81.16 24.10 891 246.01 904AL TP -7.54

72.12 94.74 16.00 25334 -9.84 14.55 VIC R4C -49.46 14.55 -49.46 94.74 18.53 180.48 955 247.49 35.25 PDMAKER1 -7.59 246.00 182.82 36.86 14.40 246.32 893 72LH8 -7.46

72RV6 72RV4 72RV2 0.00 72.19 -7.47 40.61 908 TP Total Victoria Load: 133.92 MW -10.57 210.49

44.63 94.85 224.20 71.62 -11.35 18.55 507 71.73 133 255.19

247.87 ROSSDALE -11.33 1.0565

WABAMUN4 -3.57 32.66 54.63 38.40 47.97 28.84 41.65 28.87 41.70 22.02 31.80 -7.37 184.91 58.18 0.00 0.00 0.00 0.00

37.43 37.43 205.18 145.90 145.90

64.87 40.13 344.10 260.40 -1.37 43.34 44.86 224.41 51.78 54.71513 349.18 44.60 902L LAMBTON4 64.52 1 1 542 LAMBTON8 265.57 258.28 0.971810.97181 50.89 52.00 764 246.25 1058JOIN -7.31 205.27 40.11 158.32 225.59 31.87 506 247.44 BELLAMY4 -6.80 34.62 205.27 148.89 38.51 43.23 148.89 0.00 38.51 0.00 505 JASPER 4 0.00 0.00 247.69

135 33.87 38.60 -6.48 SUNDANC4 139.66 159.21 205.81 509 247.59 518 247.55 34.51 ARGYLL W -6.72 ARGYLL E -6.71 156.16 131.19 31.79 37.85

247.96 269.62 -6.41 36.13 30.35 43.98 156.16 255.60 131.19 1.67 159.12 131.26 511 SUMMERS1 32.02 30.32

392.64 383.22 23.59 49.29 49.59 4.52 512 DOME 4 420 122.24 KEEPHIL4 521 23.71 PETROLIA

221.81 44.62 128 247.71 ELLERSLI -6.47 165.34 269.63 43.98 211.16 40.51 497 14.35 122.35 23.76 24.99 4.79 156.29 36.14 208.25 40.86 32.49 ROSS 8 -41.33 248.06 -6.28

2017SP AESO Bus - Base voltage (kV) BASE CASE (N-0) Branch - MVA/% Rate A FIG A-1 Equipment - MW/Mvar THU, NOV 03 2016 15:16 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 245.39 57 242.13 519 -10.89 LAMOURE4 32.40 68.52 15.99 138.10 26.74 -11.31 72.13 17.06 CASTLEDN 549 140.84 63 140.03 66.90 13.96 INLANDCT LAMOURE7-14.30 -12.27 113.02 71.81 530 -11.21 516 NAMAO 8 CLOVERB8 41.05 23.94 27.53 28.07 28.94 27.70 60.45 57.68

520 242.14 28.74 27.49 514 244.35 VICTORIA -11.44 CLOVERB4 -9.42 138.77 32.69 62.07 12.95 60.04 57.25 533 72VN21 528 366 140.65 VICTORIA KENNDALE 898 141.05 VISCOUNT -14.37 GENSTR T -14.19 72CN10 57.65 35.27 27.51 28.01 57.24 28.11 58.20 28.58 62.07 13.67 45.65 43.39 107.48 177.01 1 0.9783 27.61 1 3 1 9 1 76.91 72.30 . 4 2 31.27 36.05 . 3 4 96.14 25337 4 71.25 58.61 112.04 25331

-11.52 VIC 1 0.98226 1 VIC R1 28.08 1

59.19 54.59 54.59 54.595398.02 70.49 29.16 61.46 WOODCRF2 -13.33 86.71 82.37 54.94 54.94 3.90 73.50 0.98226 1 3 13.35 1 9 140 141.08 25335 . 4 2 N CALDE7. 5 -14.17 28.79 4 VIC R3 136 243.79 3 40.23 23.29 31.25 35.93 14.31 72.57 E EDMON4 -9.16

18.19 17.83 58.20 107.88 21.58 21.45 -51.59 72.02

70.17 44.85 44.85 24.10

205.73 -11.11 357 138.36 25333 STALBE7 -15.63 36.30 VIC R3C 43.58 37.76 78.56 15.50 110.21 96.41 535 70.65 218.59 1 GARNEAU8 -13.28 53.25 14.31 191.34 38.26 36.38 36.38 36.38 -51.59 502 56.05 53.81 89.71 89.71 HARDIST8 72CH11 72CH9 0.95 33.27 56.51 39.35 49.92 25338 31.19 785 243.71 37.42 VIC 2 14.60 79.18 1059A_TP -9.07 54.90 -48.77 78.86 15.57 18.19 17.83 9.50 31.53 213.40 73.97 113.48 26.92 25332 44.85 44.85 3.90 80.04 VIC R2 17.58 241.42 137 14.60 103.15 -48.77

-10.92 47.45 15.78 N CALDE4 67.72 27.52 327.62 59.57 54.94 54.94 54.94 58.20 40.38 87.26 82.90 82.54 82.54 24.10 891 243.72 904AL TP -9.00 103.22 71.53 17.59 25334 -11.40 14.31 VIC R4C -51.59 14.31 -51.59 20.38 103.22 191.47 955 243.58 37.75 PDMAKER1 -9.48 243.72 330.12 67.63 14.40 244.04 893 72LH8 -8.91

72RV6 72RV4 72RV2 0.00 71.46 -8.94 43.12 908 TP Total Victoria Load: 133.92 MW -12.08 221.46

75.13 103.32 371.48 70.61 -13.22 20.40 507 70.74 133 237.88

244.19 ROSSDALE -13.18 1.0565

WABAMUN4 -12.20 32.71 55.48 38.47 48.74 35.11 51.42 35.28 51.67 26.78 39.22 -9.10 51.76 17.47 0.00 0.00 0.00 0.00

40.56 40.56 213.86 155.94 155.94 42.22 260.40 -0.50 43.39 44.95 372.30 52.37 55.33513 75.11 902L LAMBTON4 1 1 542 LAMBTON8 373.40 354.81 0.971810.97181 71.56 72.50 764 243.98 1058JOIN -8.76 213.98 42.20 203.04 310.86 41.49 506 245.02 BELLAMY4 -8.24 36.43 213.98 159.79 41.74 59.57 159.79 0.00 41.74 0.00 505 JASPER 4 0.00 0.00 245.48

135 31.88 46.48 -7.88 SUNDANC4 130.20 189.81 214.66 509 245.15 518 245.19 36.32 ARGYLL W -8.18 ARGYLL E -8.14 183.92 122.12 29.89 45.01

245.48 278.48 -7.87 42.97 28.53 45.83 183.92 255.60 122.12 0.51 203.78 122.17 511 SUMMERS1 41.42 28.51

410.82 397.85 5.18 51.57 52.00 1.00 512 DOME 4 420 201.90 KEEPHIL4 521 39.50 PETROLIA

298.80 60.63 128 245.51 ELLERSLI -7.86 222.29 43.03 177.78 278.50 45.83 497 14.15 201.70 39.53 4.84 0.94 184.07 42.95 219.54 43.46 35.25 ROSS 8 -43.18 245.90 -7.52

2017SP AESO Bus - Base voltage (kV) LOSS OF 902L (SUNDANCE TO WABAMUN) Branch - MVA/% Rate A FIG A-2 Equipment - MW/Mvar THU, NOV 03 2016 15:16 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 247.79 57 246.20 519 -9.06 6.78 LAMOURE4 26.02 29.34 8.06 111.99 37.82 -8.94 34.67 CASTLEDN 549 143.56 63 141.24 81.94 16.82 INLANDCT LAMOURE7-11.83 -10.38 162.56 72.38 530 -9.66 516 NAMAO 8 CLOVERB8 36.43 21.06 27.50 27.52 28.92 27.66 59.92 57.15

520 246.13 28.72 27.45 514 246.59 VICTORIA -9.11 CLOVERB4 -7.91 113.08 26.40 81.64 16.76 59.51 56.72 533 72VN21 528 366 143.25 VICTORIA KENNDALE 898 143.77 VISCOUNT -12.00 GENSTR T -11.72 72CN10 57.07 93.87 32.51 27.49 27.46 56.74 27.61 57.69 28.07 81.64 17.69 45.64 43.33 164.70 1 0.9783 27.12 1 9 2 9 2 76.26 71.65 . . 44.53 50.41 0 8 8 6 95.76 80.62 71.83 25337 58.02 25331

-9.96 VIC 1 0.98226 1 VIC R1 27.58 1

59.04 54.60 54.60 54.605398.02 71.41 29.13 80.62 WOODCRF2 -11.49 85.36 81.09 54.09 54.09 3.90 72.84 0.98226 1 2 17.28 2 940 143.79 25335 . 9 8 N CALDE7. 8 -11.70 28.76 0 VIC R3 136 246.04 7 35.07 19.92 44.61 50.32 14.54 71.93 E EDMON4 -7.69

18.17 17.82 58.20 94.40 18.71 18.56 -49.49 72.59

73.22 44.12 44.12 24.10

218.80 -9.56 357 141.45 25333 STALBE7 -12.88 29.90 VIC R3C 40.98 35.27 70.70 13.83 94.56 80.91 535 71.43 207.48 1 GARNEAU8 -11.53 43.29 14.54 180.37 38.14 36.34 36.34 36.33 -49.49 502 55.14 52.93 88.25 88.25 HARDIST8 72CH11 72CH9 72.32 0.95 121.50 25338 31.18 785 245.95 30.92 VIC 2 14.82 78.51 1059A_TP -7.61 44.77 -46.76 71.05 13.90 18.17 17.82 9.50 31.52 227.02 77.18 162.78 37.88 25332 44.12 44.12 3.90 79.36 VIC R2 94.66 15.99 246.13 137 14.82 -46.76

-8.36 59.31 N CALDE4 36.99 22.65 181.80 182.47 59.42 54.95 54.95 54.95 58.20 32.79 85.91 81.61 81.25 81.25 24.10 891 245.95 904AL TP -7.55

72.10 94.75 16.00 25334 -9.85 14.54 VIC R4C -49.49 14.54 -49.49 94.75 18.53 180.47 955 247.43 35.26 PDMAKER1 -7.60 245.95 182.91 36.89 14.40 246.27 893 72LH8 -7.47

72RV6 72RV4 72RV2 0.00 72.18 -7.48 40.61 908 TP Total Victoria Load: 133.92 MW -10.58 210.47

44.65 94.85 224.28 71.55 -11.37 18.56 507 71.66 133 255.18

247.82 ROSSDALE -11.34 1.0565

WABAMUN4 -3.58 71.42 119.61 28.51 41.22 28.54 41.27 21.77 31.47 -7.38 185.02 58.22 0.00 0.00 0.00 0.00

37.53 37.53 205.16 146.17 146.17

64.90 40.13 344.24 260.40 -1.38 43.34 44.86 224.50 51.79 54.72513 349.33 44.63 902L LAMBTON4 64.54 1 1 542 LAMBTON8 265.71 258.40 0.971810.97181 50.92 52.03 764 246.20 1058JOIN -7.32 205.26 40.11 158.35 225.74 31.88 506 247.37 BELLAMY4 -6.80 34.63 205.26 149.28 38.62 43.25 149.28 0.00 38.62 0.00 505 JASPER 4 0.00 0.00 247.64

135 33.95 38.71 -6.49 SUNDANC4 139.99 159.60 205.79 509 247.52 518 247.49 34.52 ARGYLL W -6.73 ARGYLL E -6.71 156.16 131.30 31.83 37.86

247.90 269.60 -6.41 36.14 30.38 43.99 156.16 255.60 131.30 1.66 159.14 131.36 511 SUMMERS1 32.03 30.35

392.75 383.27 23.44 49.30 49.61 4.49 512 DOME 4 420 122.33 KEEPHIL4 521 23.73 PETROLIA

221.94 44.65 128 247.66 ELLERSLI -6.47 165.34 269.62 43.98 211.14 40.51 497 14.33 122.44 23.79 24.83 4.76 156.28 36.15 208.24 40.86 32.50 ROSS 8 -41.34 248.01 -6.28

2017SP AESO Bus - Base voltage (kV) LOSS OF 72RG7 (ROSSDALE TO GARNEAU) Branch - MVA/% Rate A FIG A-3 Equipment - MW/Mvar THU, NOV 03 2016 15:16 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 247.73 57 246.18 519 -9.07 6.59 LAMOURE4 26.14 28.51 7.87 112.51 37.83 -8.96 33.84 CASTLEDN 549 143.54 63 141.21 82.20 16.87 INLANDCT LAMOURE7-11.84 -10.40 162.58 72.19 530 -9.69 516 NAMAO 8 CLOVERB8 36.48 21.10 27.51 27.52 28.92 27.67 60.10 57.32

520 246.12 28.72 27.46 514 246.44 VICTORIA -9.12 CLOVERB4 -7.92 113.63 26.54 81.27 16.68 59.69 56.90 533 72VN21 528 366 143.23 VICTORIA KENNDALE 898 143.75 VISCOUNT -12.01 GENSTR T -11.74 72CN10 56.43 91.67 32.56 27.49 27.46 56.22 27.37 57.16 27.83 81.27 17.61 45.64 43.35 164.85 1 0.9783 26.89 1 9 2 9 2 76.48 71.87 . . 44.50 50.39 1 8 0 8 95.78 80.65 71.64 25337 57.38 25331

-9.99 VIC 1 0.98226 1 VIC R1 27.34 1

59.04 54.61 54.60 54.605398.02 71.45 60.46 80.29 WOODCRF2 -11.50 85.31 81.04 54.06 54.06 3.90 151.60 0.98226 1 2 17.20 2 940 143.77 25335 . 9 8 N CALDE7. 9 -11.72 1 VIC R3 136 245.94 0 35.13 19.95 44.59 50.30 14.55 E EDMON4 -7.70

18.17 17.82 58.20 92.18 18.28 18.14 -49.49 72.40

73.25 44.10 44.10 24.10

218.85 -9.58 357 141.43 25333 STALBE7 -12.90 30.20 VIC R3C 41.04 35.32 70.33 13.76 94.57 80.94 535 71.61 207.68 1 GARNEAU8 -11.45 43.71 14.55 180.52 38.13 36.33 36.33 36.33 -49.50 502 55.10 52.90 88.19 88.19 HARDIST8 72CH11 72CH9 0.95 33.20 55.64 39.28 49.16 25338 785 245.85 31.23 VIC 2 14.83 1059A_TP -7.62 45.19 -46.77 70.66 13.83 18.17 17.82 9.50 62.74 227.08 77.21 162.80 37.89 25332 44.10 44.10 3.90 159.67 VIC R2 94.52 15.97 246.10 137 14.83 -46.77

-8.38 59.33 N CALDE4 36.97 22.87 181.84 182.36 59.41 54.95 54.95 54.95 58.20 33.10 85.85 81.56 81.20 81.20 24.10 891 245.86 904AL TP -7.56

71.34 94.61 15.98 25334 -10.12 14.55 VIC R4C -49.49 14.55 -49.50 94.61 18.51 180.62 955 247.40 35.30 PDMAKER1 -7.61 245.86 182.79 36.87 14.40 246.18 893 72LH8 -7.48

72RV6 72RV4 72RV2 0.00 72.15 -7.50 40.67 908 TP Total Victoria Load: 133.92 MW -10.59 210.68

44.64 94.71 224.17 71.59 -11.38 18.53 507 71.70 133 255.17

247.79 ROSSDALE -11.35 1.0565

WABAMUN4 -3.59 32.66 54.66 38.40 48.00 28.80 41.62 28.84 41.67 21.99 31.78 -7.39 185.07 58.24 0.00 0.00 0.00 0.00

37.44 37.44 205.41 145.90 145.90

64.92 40.20 344.32 260.40 -1.40 43.35 44.87 224.39 51.82 54.75513 349.42 44.61 902L LAMBTON4 64.56 1 1 542 LAMBTON8 265.81 258.48 0.971810.97181 50.94 52.05 764 246.11 1058JOIN -7.34 205.50 40.17 158.38 225.94 31.89 506 247.33 BELLAMY4 -6.82 34.68 205.50 148.90 38.53 43.29 148.90 0.00 38.53 0.00 505 JASPER 4 0.00 0.00 247.57

135 33.94 38.59 -6.51 SUNDANC4 139.93 159.06 206.04 509 247.48 518 247.44 34.57 ARGYLL W -6.75 ARGYLL E -6.73 156.14 131.30 31.83 37.86

247.86 269.85 -6.43 36.15 30.39 44.04 156.14 255.60 131.30 1.65 159.18 131.36 511 SUMMERS1 32.05 30.36

392.89 383.35 24.15 49.32 49.63 4.63 512 DOME 4 420 122.46 KEEPHIL4 521 23.76 PETROLIA

222.12 44.70 128 247.59 ELLERSLI -6.49 165.47 269.87 44.04 211.36 40.56 497 14.34 122.57 23.82 25.63 4.92 156.27 36.15 208.44 40.91 32.53 ROSS 8 -41.35 247.94 -6.30

2017SP AESO Bus - Base voltage (kV) LOSS OF 72CH11 (CLOVERBAR TO HARDISTY) Branch - MVA/% Rate A FIG A-4 Equipment - MW/Mvar THU, NOV 03 2016 15:16 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 247.73 57 246.18 519 -9.07 6.59 LAMOURE4 26.14 28.52 7.87 112.50 37.83 -8.96 33.85 CASTLEDN 549 143.54 63 141.21 82.20 16.87 INLANDCT LAMOURE7-11.85 -10.40 162.58 72.19 530 -9.69 516 NAMAO 8 CLOVERB8 36.48 21.10 27.51 27.52 28.92 27.67 60.10 57.32

520 246.12 28.72 27.46 514 246.44 VICTORIA -9.12 CLOVERB4 -7.92 113.62 26.54 81.27 16.68 59.68 56.89 533 72VN21 528 366 143.23 VICTORIA KENNDALE 898 143.75 VISCOUNT -12.01 GENSTR T -11.74 72CN10 56.44 91.69 32.56 27.49 27.46 56.23 27.38 57.17 27.84 81.27 17.61 45.64 43.35 164.85 1 0.9783 26.89 1 9 2 9 2 76.48 71.87 . . 44.50 50.39 1 8 0 8 95.78 80.65 71.64 25337 57.39 25331

-9.99 VIC 1 0.98226 1 VIC R1 27.34 1

59.04 54.61 54.60 54.605398.02 71.45 80.29 WOODCRF2 -11.51 85.31 81.04 54.06 54.06 3.90 0.98226 1 2 17.20 2 940 143.77 25335 . 9 8 N CALDE7. 9 -11.72 60.44 1 VIC R3 136 245.94 0 35.13 19.95 44.59 50.30 14.55 151.55 E EDMON4 -7.70

18.17 17.82 58.20 92.20 18.28 18.14 -49.49 72.41

73.25 44.09 44.09 24.10

218.85 -9.58 357 141.43 25333 STALBE7 -12.90 30.20 VIC R3C 41.04 35.32 70.33 13.76 94.57 80.94 535 71.61 207.68 1 GARNEAU8 -11.45 43.71 14.55 180.52 38.13 36.33 36.33 36.33 -49.50 502 55.10 52.90 88.19 88.19 HARDIST8 72CH11 72CH9 0.95 33.20 55.64 39.28 49.16 25338 62.74 785 245.86 31.23 VIC 2 14.83 159.69 1059A_TP -7.62 45.19 -46.77 70.67 13.83 18.17 17.82 9.50 227.08 77.21 162.80 37.89 25332 44.09 44.09 3.90 VIC R2 94.53 15.97 246.10 137 14.83 -46.77

-8.38 59.33 N CALDE4 36.97 22.87 181.84 182.36 59.41 54.95 54.95 54.95 58.20 33.10 85.85 81.56 81.20 81.20 24.10 891 245.86 904AL TP -7.56

71.33 94.61 15.98 25334 -10.13 14.55 VIC R4C -49.49 14.55 -49.50 94.61 18.51 180.62 955 247.40 35.30 PDMAKER1 -7.62 245.86 182.79 36.87 14.40 246.18 893 72LH8 -7.48

72RV6 72RV4 72RV2 0.00 72.15 -7.50 40.67 908 TP Total Victoria Load: 133.92 MW -10.59 210.68

44.64 94.71 224.17 71.59 -11.38 18.53 507 71.70 133 255.17

247.79 ROSSDALE -11.36 1.0565

WABAMUN4 -3.59 32.66 54.66 38.40 47.99 28.80 41.62 28.84 41.67 21.99 31.78 -7.39 185.07 58.24 0.00 0.00 0.00 0.00

37.44 37.44 205.41 145.90 145.90

64.92 40.20 344.32 260.40 -1.40 43.35 44.87 224.39 51.82 54.75513 349.42 44.61 902L LAMBTON4 64.56 1 1 542 LAMBTON8 265.81 258.48 0.971810.97181 50.94 52.05 764 246.11 1058JOIN -7.34 205.50 40.17 158.38 225.93 31.89 506 247.33 BELLAMY4 -6.82 34.68 205.50 148.90 38.53 43.29 148.90 0.00 38.53 0.00 505 JASPER 4 0.00 0.00 247.57

135 33.94 38.59 -6.51 SUNDANC4 139.92 159.06 206.04 509 247.48 518 247.44 34.57 ARGYLL W -6.75 ARGYLL E -6.73 156.14 131.30 31.83 37.86

247.86 269.85 -6.43 36.15 30.39 44.04 156.14 255.60 131.30 1.65 159.18 131.36 511 SUMMERS1 32.05 30.36

392.89 383.35 24.15 49.32 49.63 4.63 512 DOME 4 420 122.46 KEEPHIL4 521 23.76 PETROLIA

222.12 44.70 128 247.59 ELLERSLI -6.49 165.47 269.87 44.04 211.36 40.56 497 14.34 122.57 23.82 25.62 4.92 156.27 36.15 208.44 40.91 32.53 ROSS 8 -41.36 247.95 -6.30

2017SP AESO Bus - Base voltage (kV) LOSS OF 72CH9 (CLOVERBAR TO HARDISTY) Branch - MVA/% Rate A FIG A-5 Equipment - MW/Mvar THU, NOV 03 2016 15:16 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 247.79 57 246.24 519 -9.06 6.63 LAMOURE4 26.06 28.70 7.92 112.18 37.83 -8.94 34.04 CASTLEDN 549 143.57 63 141.24 82.23 16.87 INLANDCT LAMOURE7-11.83 -10.39 162.62 72.08 530 -9.76 516 NAMAO 8 CLOVERB8 36.49 21.10 27.50 27.51

520 246.18 57.66 56.56 514 246.56 VICTORIA -9.11 CLOVERB4 -7.91 113.28 26.45 81.23 16.67 119.99 116.98 533 72VN21 528 366 143.26 VICTORIA KENNDALE 898 143.78 VISCOUNT -12.00 GENSTR T -11.72 72CN10 56.77 92.92 32.53 27.49 27.46 56.49 27.49 57.43 27.95 81.23 17.60 45.64 43.34 164.76 1 0.9783 27.00 1 9 2 9 2 76.34 71.73 . . 44.54 50.42 0 8 9 8 95.78 80.64 71.76 25337 57.72 25331

-9.97 VIC 1 0.98226 1 VIC R1 27.46 1

59.03 54.61 54.61 54.605398.02 71.47 29.13 80.26 WOODCRF2 -11.49 85.28 81.02 54.04 54.04 3.90 72.92 0.98226 1 2 17.19 2 940 143.80 25335 . 9 9 N CALDE7. 0 -11.70 28.76 0 VIC R3 136 246.03 8 35.13 19.95 44.63 50.33 14.55 72.00 E EDMON4 -7.69

18.17 17.82 58.20 93.45 18.52 18.38 -49.47 72.53

73.25 44.08 44.08 24.10

218.90 -9.57 357 141.46 25333 STALBE7 -12.88 30.23 VIC R3C 41.00 35.29 70.54 13.79 94.58 80.93 535 71.63 207.57 1 GARNEAU8 -11.43 43.73 14.55 180.44 38.13 36.33 36.33 36.33 -49.47 502 55.08 52.88 88.16 88.16 HARDIST8 72CH11 72CH9 0.95 33.20 55.62 39.28 49.15 25338 31.18 785 245.94 31.25 VIC 2 14.83 78.59 1059A_TP -7.61 45.22 -46.75 70.88 13.87 18.17 17.82 9.50 31.52 227.12 77.21 162.84 37.89 25332 44.08 44.08 3.90 79.44 VIC R2 94.60 15.98 246.16 137 14.83 -46.75

-8.36 59.29 N CALDE4 36.97 22.89 181.76 182.37 59.41 54.96 54.95 54.95 58.20 33.12 85.83 81.53 81.18 81.18 24.10 891 245.95 904AL TP -7.55

72.03 94.68 15.99 25334 -9.85 14.55 VIC R4C -49.47 14.55 -49.47 94.68 18.52 180.53 955 247.45 35.27 PDMAKER1 -7.60 245.95 182.81 36.86 14.40 246.26 893 72LH8 -7.47

72RV6 72RV4 72RV2 0.00 72.18 -7.48 40.63 908 TP Total Victoria Load: 133.92 MW -10.58 210.57

44.63 94.79 224.19 71.61 -11.36 18.54 507 71.72 133 255.18

247.84 ROSSDALE -11.34 1.0565

WABAMUN4 -3.58 32.66 54.64 38.40 47.98 28.82 41.64 28.86 41.69 22.01 31.79 -7.38 184.97 58.21 0.00 0.00 0.00 0.00

37.43 37.43 205.27 145.90 145.90

64.89 40.16 344.19 260.40 -1.38 43.34 44.86 224.40 51.80 54.72513 349.27 44.60 902L LAMBTON4 64.53 1 1 542 LAMBTON8 265.67 258.36 0.971810.97181 50.91 52.02 764 246.19 1058JOIN -7.32 205.36 40.13 158.34 225.73 31.88 506 247.40 BELLAMY4 -6.80 34.65 205.36 148.90 38.52 43.25 148.90 0.00 38.52 0.00 505 JASPER 4 0.00 0.00 247.64

135 33.90 38.60 -6.49 SUNDANC4 139.77 159.15 205.90 509 247.54 518 247.51 34.54 ARGYLL W -6.73 ARGYLL E -6.71 156.16 131.23 31.81 37.85

247.92 269.71 -6.42 36.14 30.37 44.00 156.16 255.60 131.23 1.66 159.14 131.30 511 SUMMERS1 32.03 30.34

392.74 383.27 23.81 49.30 49.60 4.56 512 DOME 4 420 122.33 KEEPHIL4 521 23.73 PETROLIA

221.93 44.65 128 247.66 ELLERSLI -6.47 165.39 269.73 44.00 211.24 40.53 497 14.34 122.44 23.79 25.25 4.84 156.28 36.15 208.33 40.88 32.51 ROSS 8 -41.34 248.01 -6.28

2017SP AESO Bus - Base voltage (kV) LOSS OF 72CK12 (CLOVERBAR TO KENNEDALE) Branch - MVA/% Rate A FIG A-6 Equipment - MW/Mvar THU, NOV 03 2016 15:16 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 247.79 57 246.24 519 -9.06 6.63 LAMOURE4 26.06 28.70 7.92 112.18 37.83 -8.94 34.03 CASTLEDN 549 143.57 63 141.24 82.23 16.87 INLANDCT LAMOURE7-11.83 -10.38 162.61 72.08 530 -9.76 516 NAMAO 8 CLOVERB8 36.49 21.10 27.50 27.51 57.66 56.57 119.98 117.00 520 246.18 514 246.56 VICTORIA -9.11 CLOVERB4 -7.91 113.29 26.45 81.23 16.67 533 72VN21 528 366 143.26 VICTORIA KENNDALE 898 143.78 VISCOUNT -12.00 GENSTR T -11.72 72CN10 56.76 92.92 32.53 27.49 27.46 56.48 27.49 57.43 27.95 81.23 17.60 45.64 43.34 164.76 1 0.9783 27.00 1 9 2 9 2 76.34 71.73 . . 44.54 50.42 0 8 9 8 95.78 80.64 71.76 25337 57.71 25331

-9.96 VIC 1 0.98226 1 VIC R1 27.45 1

59.03 54.61 54.61 54.605398.02 71.47 29.13 80.26 WOODCRF2 -11.49 85.28 81.02 54.04 54.04 3.90 72.92 0.98226 1 2 17.19 2 940 143.80 25335 . 9 9 N CALDE7. 0 -11.70 28.76 0 VIC R3 136 246.03 8 35.13 19.95 44.63 50.33 14.55 72.00 E EDMON4 -7.69

18.17 17.82 58.20 93.44 18.52 18.38 -49.47 72.52

73.25 44.08 44.08 24.10

218.90 -9.56 357 141.46 25333 STALBE7 -12.88 30.23 VIC R3C 41.00 35.29 70.53 13.79 94.58 80.93 535 71.63 207.57 1 GARNEAU8 -11.43 43.73 14.55 180.44 38.13 36.33 36.33 36.33 -49.47 502 55.08 52.88 88.16 88.16 HARDIST8 72CH11 72CH9 0.95 33.20 55.62 39.28 49.15 25338 31.18 785 245.94 31.25 VIC 2 14.83 78.59 1059A_TP -7.61 45.22 -46.75 70.87 13.86 18.17 17.82 9.50 31.52 227.12 77.21 162.84 37.89 25332 44.08 44.08 3.90 79.44 VIC R2 94.60 15.98 246.16 137 14.83 -46.75

-8.36 59.29 N CALDE4 36.97 22.89 181.76 182.37 59.41 54.96 54.95 54.95 58.20 33.12 85.83 81.53 81.18 81.18 24.10 891 245.95 904AL TP -7.55

72.03 94.68 15.99 25334 -9.85 14.55 VIC R4C -49.47 14.55 -49.47 94.68 18.52 180.53 955 247.45 35.27 PDMAKER1 -7.60 245.95 182.81 36.86 14.40 246.26 893 72LH8 -7.47

72RV6 72RV4 72RV2 0.00 72.18 -7.48 40.63 908 TP Total Victoria Load: 133.92 MW -10.58 210.57

44.63 94.79 224.19 71.61 -11.36 18.54 507 71.72 133 255.18

247.84 ROSSDALE -11.34 1.0565

WABAMUN4 -3.58 32.66 54.64 38.40 47.98 28.82 41.64 28.86 41.69 22.01 31.79 -7.38 184.97 58.21 0.00 0.00 0.00 0.00

37.43 37.43 205.27 145.90 145.90

64.89 40.16 344.19 260.40 -1.38 43.34 44.86 224.40 51.80 54.72513 349.28 44.60 902L LAMBTON4 64.53 1 1 542 LAMBTON8 265.67 258.36 0.971810.97181 50.91 52.02 764 246.19 1058JOIN -7.32 205.36 40.13 158.34 225.73 31.88 506 247.40 BELLAMY4 -6.80 34.65 205.36 148.90 38.52 43.25 148.90 0.00 38.52 0.00 505 JASPER 4 0.00 0.00 247.64

135 33.90 38.60 -6.49 SUNDANC4 139.77 159.15 205.90 509 247.54 518 247.51 34.54 ARGYLL W -6.73 ARGYLL E -6.71 156.16 131.23 31.81 37.85

247.92 269.71 -6.42 36.14 30.37 44.00 156.16 255.60 131.23 1.66 159.14 131.30 511 SUMMERS1 32.03 30.34

392.74 383.27 23.81 49.30 49.60 4.56 512 DOME 4 420 122.33 KEEPHIL4 521 23.73 PETROLIA

221.93 44.65 128 247.66 ELLERSLI -6.47 165.39 269.73 44.00 211.24 40.53 497 14.34 122.44 23.79 25.25 4.84 156.28 36.15 208.33 40.88 32.51 ROSS 8 -41.34 248.01 -6.28

2017SP AESO Bus - Base voltage (kV) LOSS OF 72CK13 (CLOVERBAR TO KENNEDALE) Branch - MVA/% Rate A FIG A-7 Equipment - MW/Mvar THU, NOV 03 2016 15:16 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 250.54 57 250.07 519 -7.39 2.80 LAMOURE4 14.59 23.13 3.52 30.66 18.27 -7.24 CASTLEDN 120.46 549 143.28 63 142.30 68.87 13.14 INLANDCT LAMOURE7-10.31 -8.66 159.34 72.26 530 -7.50 516 NAMAO 8 CLOVERB8 34.90 17.72 31.45 31.53 27.98 27.11 49.48 47.81

520 249.87 27.79 26.91 514 251.08 VICTORIA -7.37 CLOVERB4 -6.17 120.65 15.05 23.12 78.81 49.14 47.46 533 72VN21 528 366 143.05 VICTORIA KENNDALE 898 143.54 VISCOUNT -10.60 GENSTR T -10.20 72CN10 44.94 70.67 25.20 31.44 31.46 78.81 16.82 44.21 42.59 44.50 21.27 45.25 21.63 161.08 1 0.9783 21.40 1 7 1 8 8 73.96 70.57 . . 56.46 60.45 2 8 1 0 87.42 66.22 71.75 25337 45.70 25331 -7.82 VIC 1 1.0062 1 VIC R1 21.76 1

57.79 54.56 54.56 54.5653919.70 71.93 28.97 77.14 WOODCRF2 -9.39 1.0062 82.96 78.81 52.56 52.56 2.70 72.59 1 1 16.41 8 740 143.55 25335 . 8 8 N CALDE7. 1 -10.17 28.61 2 VIC R3 136 250.80 0 33.82 17.02 56.65 60.44 14.95 71.70 E EDMON4 -6.00

18.15 17.93 50.30 71.18 13.65 13.54 -47.52 72.45

69.29 43.17 43.17 16.70

206.73 -7.38 357 141.98 25333 STALBE7 -11.40 27.65 VIC R3C 39.50 73.37 14.08 34.43 86.65 66.36 535 72.10 205.88 1 GARNEAU8 -9.30 39.75 14.95 179.50 37.57 36.30 36.30 36.30 -47.52 502 53.94 51.78 86.33 86.33 HARDIST8 72CH11 72CH9 0.98 19.01 29.33 22.77 25.32 25338 30.37 785 250.72 28.57 VIC 2 15.13 76.58 1059A_TP -5.91 41.08 -44.80 73.70 14.14 18.15 17.93 19.70 30.70 211.83 70.80 159.56 30.66 25332 43.17 43.17 2.70 77.42 VIC R2 98.32 13.24 250.38 137 15.13 -44.80 -6.69 37.14 N CALDE4 37.66 21.00 169.30 195.97 58.16 54.91 54.91 54.91 50.30 30.20 83.49 79.31 78.97 78.97 16.70 891 250.73 904AL TP -5.85

72.00 98.41 13.25 25334 -7.70 14.95 VIC R4C -47.52 14.95 -47.52 98.41 18.88 179.60 955 251.84 34.43 PDMAKER1 -5.91 250.72 196.52 37.54 14.40 250.97 893 0.00 72LH8 -5.78 72RV6 72RV4 72RV2 72.00 -5.80 30.80 908 TP Total Victoria Load: 140.00 MW -8.43 208.73

37.19 98.53 233.74 72.06 -9.29 18.91 507 72.13 133 256.07

252.23 ROSSDALE -9.23 1.0239

WABAMUN4 -2.13 19.58 30.20 22.60 25.13 27.21 39.08 27.30 39.21 20.71 29.74 -5.68 171.41 36.77 0.00 0.00 0.00 0.00 28.46 28.46 200.38 128.53 128.53

64.27 38.45 342.06 260.40 0.14 37.33 38.27 233.97 44.72 45.79513 346.38 37.16 902L LAMBTON4 64.00 1 1 542 LAMBTON8 247.79 242.71 1.00921.0092 39.30 39.74 764 250.91 1058JOIN -5.63 200.45 38.44 157.91 207.03 25.85 506 252.30 BELLAMY4 -5.11 26.97 200.45 128.06 0.00 28.20 0.00 32.84 128.06 28.20 505 JASPER 4 0.00 0.00 252.02

135 23.74 27.68 -4.83 SUNDANC4 119.54 139.36 200.92 509 252.35 518 252.26 26.92 ARGYLL W -5.05 ARGYLL E -5.03 149.86 120.32 23.89 29.76

252.31 272.87 -4.76 27.58 22.13 36.45 149.86 255.60 120.32 3.05 158.73 120.51 511 SUMMERS1 25.98 22.17

377.01 372.37 24.95 47.33 47.35 3.66 512 DOME 4 420 118.89 KEEPHIL4 521 22.67 PETROLIA

204.46 33.48 128 252.03 ELLERSLI -4.81 209.35 30.76 161.69 272.88 36.45 497 14.43 118.90 22.69 26.56 3.90 150.16 27.66 206.60 39.44 25.20 ROSS 8 -39.23 252.25 -4.63

2017WP AESO Bus - Base voltage (kV) BASE CASE (N-0) Branch - MVA/% Rate B FIG A-1 Equipment - MW/Mvar WED, NOV 16 2016 10:44 100.0%Rate B

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 250.44 57 249.98 519 -7.41 2.77 LAMOURE4 14.43 23.13 3.47 30.67 18.03 -7.25 CASTLEDN 120.38 549 143.24 63 142.25 68.86 13.14 INLANDCT LAMOURE7-10.33 -8.68 159.35 72.06 530 -7.52 516 NAMAO 8 CLOVERB8 34.90 17.73 31.45 31.54 27.99 27.12 49.63 47.96

520 249.78 27.79 26.92 514 250.89 VICTORIA -7.39 CLOVERB4 -6.19 120.61 15.07 23.13 78.87 49.29 47.60 533 72VN21 528 366 143.01 VICTORIA KENNDALE 898 143.49 VISCOUNT -10.62 GENSTR T -10.22 72CN10 43.45 69.19 25.23 31.44 31.47 78.87 16.84 44.21 42.61 43.11 20.62 43.84 20.97 161.20 1 0.9783 20.75 1 7 1 8 8 74.17 70.78 . . 56.42 60.42 2 7 3 9 87.41 66.23 71.55 25337 44.18 25331 -7.85 VIC 1 1.0062 1 VIC R1 21.10 1

57.79 54.56 54.56 54.5653919.70 71.90 59.37 77.20 WOODCRF2 -9.41 1.0062 83.00 78.85 52.59 52.59 2.70 149.19 1 1 16.43 8 740 143.51 25335 . 8 8 N CALDE7. 0 -10.19 2 VIC R3 136 250.65 2 33.82 17.03 56.61 60.41 14.94 E EDMON4 -6.01

18.15 17.93 50.30 69.65 13.37 13.27 -47.55 72.25

69.30 43.19 43.19 16.70

206.68 -7.40 357 141.93 25333 STALBE7 -11.42 27.64 VIC R3C 39.54 73.04 14.02 34.47 86.64 66.37 535 72.07 205.98 1 GARNEAU8 -9.32 39.75 14.94 179.55 37.58 36.30 36.30 36.30 -47.55 502 53.97 51.81 86.38 86.38 HARDIST8 72CH11 72CH9 0.98 19.01 29.34 22.77 25.34 25338 785 250.58 28.56 VIC 2 15.13 1059A_TP -5.93 41.08 -44.82 73.37 14.09 18.15 17.93 19.70 61.10 211.78 70.80 159.58 30.67 25332 43.19 43.19 2.70 155.67 VIC R2 98.18 13.23 250.30 137 15.13 -44.83 -6.71 37.17 N CALDE4 37.66 20.99 169.37 195.94 58.16 54.91 54.91 54.91 50.30 30.20 83.53 79.35 79.00 79.00 16.70 891 250.59 904AL TP -5.87

71.26 98.27 13.24 25334 -7.99 14.94 VIC R4C -47.55 14.94 -47.55 98.27 18.87 179.65 955 251.75 34.46 PDMAKER1 -5.93 250.58 196.49 37.55 14.40 250.83 893 0.00 72LH8 -5.79 72RV6 72RV4 72RV2 71.96 -5.81 30.83 908 TP Total Victoria Load: 140.00 MW -8.45 208.84

37.19 98.38 233.71 72.03 -9.31 18.89 507 72.10 133 256.05

252.15 ROSSDALE -9.25 1.0239

WABAMUN4 -2.15 19.58 30.21 22.60 25.14 27.20 39.09 27.29 39.21 20.70 29.75 -5.70 171.49 36.79 0.00 0.00 0.00 0.00 28.47 28.47 200.52 128.53 128.53

64.30 38.50 342.22 260.40 0.12 37.33 38.27 233.94 44.75 45.82513 346.56 37.17 902L LAMBTON4 64.03 1 1 542 LAMBTON8 247.92 242.81 1.00921.0092 39.32 39.77 764 250.78 1058JOIN -5.65 200.60 38.49 157.97 207.21 25.87 506 252.19 BELLAMY4 -5.13 27.01 200.60 128.06 0.00 28.21 0.00 32.87 128.06 28.21 505 JASPER 4 0.00 0.00 251.90

135 23.77 27.70 -4.85 SUNDANC4 119.65 139.43 201.07 509 252.24 518 252.15 26.95 ARGYLL W -5.07 ARGYLL E -5.05 150.06 120.23 23.88 29.82

252.21 273.02 -4.77 27.63 22.13 36.49 150.06 255.60 120.23 3.03 158.80 120.41 511 SUMMERS1 26.00 22.16

377.11 372.38 25.57 47.34 47.37 3.75 512 DOME 4 420 118.98 KEEPHIL4 521 22.69 PETROLIA

204.64 33.53 128 251.92 ELLERSLI -4.83 209.46 30.79 161.78 273.03 36.49 497 14.42 118.99 22.72 27.23 4.00 150.36 27.71 206.70 39.48 25.22 ROSS 8 -39.25 252.14 -4.64

2017WP AESO Bus - Base voltage (kV) LOSS OF 72CH11 (CLOVERBAR TO HARDISTY) Branch - MVA/% Rate B FIG A-2 Equipment - MW/Mvar WED, NOV 16 2016 10:44 100.0%Rate B

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 250.44 57 249.98 519 -7.41 2.77 LAMOURE4 14.43 23.13 3.47 30.67 18.03 -7.26 CASTLEDN 120.38 549 143.24 63 142.25 68.86 13.14 INLANDCT LAMOURE7-10.33 -8.68 159.35 72.06 530 -7.52 516 NAMAO 8 CLOVERB8 34.90 17.73 31.45 31.54 27.99 27.12 49.63 47.95

520 249.78 27.79 26.92 514 250.89 VICTORIA -7.39 CLOVERB4 -6.19 120.61 15.07 23.13 78.87 49.28 47.60 533 72VN21 528 366 143.01 VICTORIA KENNDALE 898 143.49 VISCOUNT -10.62 GENSTR T -10.22 72CN10 43.47 69.21 25.23 31.44 31.47 78.87 16.84 44.21 42.61 43.13 20.63 43.85 20.97 161.20 1 0.9783 20.76 1 7 1 8 8 74.17 70.78 . . 56.42 60.42 2 7 2 9 87.41 66.23 71.55 25337 44.20 25331 -7.85 VIC 1 1.0062 1 VIC R1 21.10 1

57.79 54.56 54.56 54.5653919.70 71.90 77.20 WOODCRF2 -9.41 1.0062 83.00 78.85 52.59 52.59 2.70 1 1 16.43 8 740 143.51 25335 . 8 8 N CALDE7. 0 -10.19 59.36 2 VIC R3 136 250.65 2 33.82 17.03 56.61 60.41 14.94 149.15 E EDMON4 -6.01

18.15 17.93 50.30 69.66 13.37 13.27 -47.55 72.26

69.30 43.19 43.19 16.70

206.68 -7.40 357 141.93 25333 STALBE7 -11.42 27.64 VIC R3C 39.54 73.05 14.02 34.47 86.64 66.37 535 72.07 205.98 1 GARNEAU8 -9.32 39.75 14.94 179.56 37.58 36.30 36.30 36.30 -47.55 502 53.97 51.81 86.38 86.38 HARDIST8 72CH11 72CH9 0.98 19.01 29.34 22.77 25.34 25338 61.10 785 250.58 28.56 VIC 2 15.13 155.69 1059A_TP -5.93 41.08 -44.82 73.37 14.09 18.15 17.93 19.70 211.78 70.80 159.58 30.67 25332 43.19 43.19 2.70 VIC R2 98.18 13.23 250.30 137 15.13 -44.83 -6.71 37.17 N CALDE4 37.66 20.99 169.37 195.94 58.16 54.91 54.91 54.91 50.30 30.20 83.53 79.35 79.00 79.00 16.70 891 250.59 904AL TP -5.87

71.25 98.27 13.24 25334 -8.00 14.94 VIC R4C -47.55 14.94 -47.55 98.27 18.87 179.66 955 251.75 34.46 PDMAKER1 -5.93 250.59 196.49 37.55 14.40 250.83 893 0.00 72LH8 -5.79 72RV6 72RV4 72RV2 71.96 -5.81 30.83 908 TP Total Victoria Load: 140.00 MW -8.45 208.84

37.19 98.38 233.71 72.03 -9.31 18.89 507 72.10 133 256.05

252.15 ROSSDALE -9.26 1.0239

WABAMUN4 -2.15 19.58 30.21 22.60 25.14 27.20 39.09 27.29 39.21 20.70 29.75 -5.70 171.49 36.79 0.00 0.00 0.00 0.00 28.47 28.47 200.52 128.53 128.53

64.30 38.50 342.22 260.40 0.12 37.33 38.27 233.94 44.75 45.82513 346.56 37.17 902L LAMBTON4 64.03 1 1 542 LAMBTON8 247.92 242.81 1.00921.0092 39.32 39.77 764 250.78 1058JOIN -5.65 200.60 38.49 157.96 207.21 25.87 506 252.19 BELLAMY4 -5.13 27.01 200.60 128.06 0.00 28.21 0.00 32.87 128.06 28.21 505 JASPER 4 0.00 0.00 251.91

135 23.77 27.70 -4.85 SUNDANC4 119.65 139.43 201.07 509 252.24 518 252.15 26.95 ARGYLL W -5.07 ARGYLL E -5.05 150.05 120.23 23.88 29.82

252.21 273.02 -4.78 27.63 22.13 36.49 150.05 255.60 120.23 3.03 158.79 120.42 511 SUMMERS1 26.00 22.16

377.11 372.38 25.56 47.34 47.37 3.75 512 DOME 4 420 118.98 KEEPHIL4 521 22.69 PETROLIA

204.64 33.53 128 251.92 ELLERSLI -4.83 209.46 30.79 161.78 273.03 36.49 497 14.42 118.99 22.72 27.23 4.00 150.36 27.71 206.70 39.48 25.22 ROSS 8 -39.26 252.15 -4.64

2017WP AESO Bus - Base voltage (kV) LOSS OF 72CH9 (CLOVERBAR TO HARDISTY) Branch - MVA/% Rate B FIG A-3 Equipment - MW/Mvar WED, NOV 16 2016 10:45 100.0%Rate B

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 Attachment B

Post-Project Power Flow Diagrams (Scenarios 3 and 4)

November 2016 248.16 57 247.28 519 -9.06 4.07 LAMOURE4 25.98 17.64 5.24 111.98 38.27 -8.93 22.62 CASTLEDN 549 141.34 63 141.20 83.79 17.12 INLANDCT LAMOURE7-11.81 -10.40 165.23 72.51 530 -9.65 516 NAMAO 8 CLOVERB8 27.67 16.00 27.43 27.87 28.81 27.55 59.60 56.83

520 247.20 28.61 27.35 514 247.08 VICTORIA -9.10 CLOVERB4 -7.91 113.02 26.33 84.07 17.18 59.19 56.40 533 72VN21 528 366 141.13 VICTORIA KENNDALE 898 141.55 VISCOUNT -11.99 GENSTR T -11.70 72CN10 56.73 93.16 32.52 27.42 27.82 56.42 27.40 57.36 27.86 84.07 18.14 45.48 43.17 165.04 1 0.9783 26.91 1 9 1 5 6 75.86 71.25 . . 42.04 48.31 1 1 2 4 88.78 75.91 71.96 25337 57.68 25331

-9.95 VIC 1 0.98226 1 VIC R1 27.36 1

61.34 56.70 56.70 56.7053914.10 71.69 29.02 82.97 WOODCRF2 -11.52 88.34 83.92 55.98 55.98 3.90 72.44 0.98226 1 1 17.71 6 940 141.57 25335 . 5 1 N CALDE7. 5 -11.68 28.65 1 VIC R3 136 246.54 1 26.83 15.48 42.13 48.27 14.59 71.53 E EDMON4 -7.69

18.89 18.53 58.20 93.69 18.53 18.39 -49.84 72.72

66.67 45.74 45.74 24.10

196.17 -9.55 357 139.70 25333 STALBE7 -12.91 31.06 VIC R3C 41.05 35.35 70.44 13.75 87.86 76.12 535 71.85 208.27 1 GARNEAU8 -11.47 44.80 14.59 181.13 39.68 37.79 37.79 37.79 -49.84 502 57.15 54.87 91.48 91.48 HARDIST8 72CH11 72CH9 0.98 33.05 55.20 39.11 48.78 25338 31.07 785 246.47 32.11 VIC 2 14.87 78.09 1059A_TP -7.61 46.31 -47.00 70.76 13.81 18.89 18.53 9.50 31.41 201.45 68.13 165.46 38.30 25332 45.74 45.74 3.90 78.94 VIC R2 94.89 15.99 247.43 137 14.87 -47.01

-8.35 57.99 N CALDE4 35.58 23.53 178.68 176.42 61.73 57.06 57.06 57.06 58.20 33.94 88.90 84.46 84.09 84.09 24.10 891 246.48 904AL TP -7.55

72.24 94.97 16.00 25334 -9.84 14.59 VIC R4C -49.84 14.59 -49.84 94.97 18.54 181.22 955 248.42 35.33 PDMAKER1 -7.60 246.48 176.75 35.51 14.40 246.79 893 72LH8 -7.47

72RV6 72RV4 72RV2 0.00 71.91 -7.49 40.68 908 TP Total Victoria Load: 140.00 MW -10.56 211.25

43.19 95.07 217.82 71.83 -11.40 18.56

507 71.94 1.05 133 255.39 248.73 ROSSDALE -11.37

WABAMUN4 -3.60 32.52 54.24 38.23 47.62 29.71 42.79 29.77 42.87 22.68 32.67 -7.38 181.52 57.07 0.00 0.00 0.00 0.00

37.65 37.65 205.80 147.21 147.21

64.43 40.17 341.99 260.40 -1.40 43.21 44.72 217.99 51.83 54.43513 346.84 43.17 902L LAMBTON4 64.08 1 1 542 LAMBTON8 262.43 255.63 0.971810.97181 50.29 51.29 764 246.73 1058JOIN -7.33 205.89 40.15 157.87 223.54 31.67 506 247.99 BELLAMY4 -6.82 34.66 205.89 150.13 38.74 42.83 150.13 0.00 38.74 0.00 505 JASPER 4 0.00 0.00 248.21

135 34.34 38.67 -6.50 SUNDANC4 141.93 159.82 206.43 509 248.14 518 248.10 34.54 ARGYLL W -6.74 ARGYLL E -6.73 157.56 133.17 32.20 38.10

248.53 270.02 -6.42 36.38 30.74 43.95 157.56 255.60 133.17 1.65 158.82 133.24 511 SUMMERS1 31.89 30.71

391.66 382.87 26.24 49.16 49.43 5.02 512 DOME 4 420 121.13 KEEPHIL4 521 23.45 PETROLIA

219.95 44.16 128 248.23 ELLERSLI -6.48 165.65 270.03 43.95 211.92 40.57 497 14.39 121.22 23.49 27.84 5.33 157.70 36.39 209.02 40.92 32.49 ROSS 8 -41.37 248.55 -6.29

2017SP AESO Bus - Base voltage (kV) BASE CASE (N-0) Branch - MVA/% Rate A FIG A-1 Equipment - MW/Mvar THU, NOV 03 2016 15:13 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 245.75 57 243.23 519 -10.89 LAMOURE4 32.40 56.07 13.07 138.31 25.76 -11.30 59.72 14.06 CASTLEDN 549 138.70 63 139.98 67.89 14.10 INLANDCT LAMOURE7-14.29 -12.28 109.39 71.93 530 -11.21 516 NAMAO 8 CLOVERB8 39.52 23.06 27.45 28.42 28.84 27.59 60.13 57.36

520 243.21 28.64 27.38 514 244.81 VICTORIA -11.43 CLOVERB4 -9.43 138.95 32.67 64.90 13.48 59.72 56.93 533 72VN21 528 366 138.60 VICTORIA KENNDALE 898 138.92 VISCOUNT -14.36 GENSTR T -14.17 72CN10 57.31 35.25 27.44 28.37 56.92 27.90 57.87 28.37 64.90 14.23 45.50 43.22 106.94 177.28 1 0.9783 27.41 1 3 1 2 1 76.51 71.91 . 0 2 28.84 33.75 . 8 3 91.39 25337 9 71.38 58.27 104.90 25331

-11.51 VIC 1 0.98226 1 VIC R1 27.87 1

61.50 56.69 56.69 56.6853914.10 70.71 29.05 64.17 WOODCRF2 -13.37 89.82 85.33 56.91 56.91 3.90 73.10 0.98226 1 3 13.89 1 2 140 138.94 25335 . 0 2 N CALDE7. 9 -14.15 28.68 3 VIC R3 136 244.26 9 39.15 23.01 28.86 33.68 14.34 72.18 E EDMON4 -9.17

18.92 18.54 58.20 107.35 21.43 21.30 -51.97 72.15

63.70 46.54 46.54 24.10

183.93 -11.10 357 136.69 25333 STALBE7 -15.65 37.19 VIC R3C 43.62 37.82 78.41 15.44 103.45 91.60 535 70.87 219.26 1 GARNEAU8 -13.32 54.40 14.34 191.99 39.82 37.84 37.84 37.84 -51.97 502 58.15 55.83 93.08 93.08 HARDIST8 72CH11 72CH9 0.98 33.12 56.08 39.18 49.54 25338 31.09 785 244.20 38.33 VIC 2 14.63 78.77 1059A_TP -9.07 56.06 -49.04 78.69 15.50 18.92 18.54 9.50 31.42 188.84 65.09 109.79 25.90 25332 46.54 46.54 3.90 79.62 VIC R2 17.58 242.77 137 14.63 103.38 -49.04

-10.91 50.40 16.67 N CALDE4 66.28 28.21 322.45 61.89 57.05 57.05 57.05 58.20 41.26 90.40 85.88 85.50 85.50 24.10 891 244.21 904AL TP -9.01 103.45 71.65 17.59 25334 -11.39 14.34 VIC R4C -51.97 14.34 -51.97 20.38 103.45 192.11 955 244.59 37.80 PDMAKER1 -9.49 244.22 324.52 66.21 14.40 244.52 893 72LH8 -8.92

72RV6 72RV4 72RV2 0.00 71.19 -8.94 43.17 908 TP Total Victoria Load: 140.00 MW -12.06 222.12

73.64 103.54 365.61 70.83 -13.27 20.40

507 70.96 1.05 133 238.72 245.12 ROSSDALE -13.22

WABAMUN4 -12.21 32.57 55.07 38.30 48.37 36.06 52.64 36.24 52.92 27.49 40.14 -9.11 55.19 18.57 0.00 0.00 0.00 0.00

40.77 40.77 214.39 157.22 157.22 42.23 260.40 -0.52 43.26 44.81 366.30 52.42 55.04513 73.62 902L LAMBTON4 1 1 542 LAMBTON8 370.31 352.82 0.971810.97181 70.96 71.83 764 244.48 1058JOIN -8.77 214.50 42.21 200.52 308.95 40.82 506 245.59 BELLAMY4 -8.26 36.44 214.50 160.98 41.95 59.20 160.98 0.00 41.95 0.00 505 JASPER 4 0.00 0.00 246.02

135 32.38 46.46 -7.89 SUNDANC4 132.53 190.17 215.18 509 245.73 518 245.75 36.33 ARGYLL W -8.19 ARGYLL E -8.15 185.05 124.04 30.29 45.18

246.08 278.79 -7.89 43.13 28.91 45.79 185.05 255.60 124.04 0.49 201.26 124.09 511 SUMMERS1 40.81 28.88

409.43 397.22 4.70 51.40 51.79 0.91 512 DOME 4 420 201.23 KEEPHIL4 521 39.29 PETROLIA

297.34 60.21 128 246.04 ELLERSLI -7.87 222.96 43.06 178.03 278.81 45.78 497 14.19 201.03 39.31 6.35 1.23 185.21 43.12 220.21 43.50 35.22 ROSS 8 -43.22 246.41 -7.54

2017SP AESO Bus - Base voltage (kV) LOSS OF 902L (SUNDANCE TO WABAMUN) Branch - MVA/% Rate A FIG A-2 Equipment - MW/Mvar THU, NOV 03 2016 15:13 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 248.11 57 247.21 519 -9.07 4.17 LAMOURE4 25.99 18.08 5.35 112.01 38.28 -8.94 23.09 CASTLEDN 549 141.31 63 141.18 83.52 17.07 INLANDCT LAMOURE7-11.82 -10.41 165.22 72.50 530 -9.66 516 NAMAO 8 CLOVERB8 27.65 15.99 27.43 27.88 28.81 27.55 59.61 56.84

520 247.12 28.61 27.35 514 247.03 VICTORIA -9.11 CLOVERB4 -7.92 113.05 26.34 84.53 17.28 59.20 56.41 533 72VN21 528 366 141.10 VICTORIA KENNDALE 898 141.52 VISCOUNT -12.00 GENSTR T -11.71 72CN10 56.75 93.22 32.52 27.42 27.82 56.43 27.41 57.37 27.87 84.53 18.24 45.48 43.17 165.03 1 0.9783 26.92 1 9 1 5 6 75.88 71.27 . . 42.02 48.29 1 1 2 1 88.75 75.91 71.95 25337 57.70 25331

-9.96 VIC 1 0.98226 1 VIC R1 27.38 1

61.35 56.70 56.70 56.7053914.10 71.62 29.02 83.37 WOODCRF2 -11.54 88.44 84.02 56.04 56.04 3.90 72.45 0.98226 1 1 17.81 6 940 141.54 25335 . 5 1 N CALDE7. 2 -11.69 28.65 1 VIC R3 136 246.49 2 26.81 15.47 42.11 48.25 14.57 71.54 E EDMON4 -7.70

18.90 18.53 58.20 93.75 18.55 18.40 -49.87 72.71

66.66 45.79 45.79 24.10

196.07 -9.56 357 139.67 25333 STALBE7 -12.92 30.73 VIC R3C 41.06 35.35 70.45 13.75 87.83 76.12 535 71.64 208.25 1 GARNEAU8 -11.58 44.37 14.57 181.12 39.69 37.79 37.79 37.79 -49.87 502 57.22 54.93 91.59 91.59 HARDIST8 72CH11 72CH9 72.00 0.98 120.61 25338 31.07 785 246.42 31.77 VIC 2 14.85 78.11 1059A_TP -7.62 45.87 -47.03 70.78 13.82 18.90 18.53 9.50 31.41 201.34 68.11 165.45 38.31 25332 45.79 45.79 3.90 78.95 VIC R2 94.89 15.99 247.37 137 14.85 -47.03

-8.36 58.03 N CALDE4 35.60 23.28 178.76 176.48 61.74 57.06 57.06 57.06 58.20 33.62 89.01 84.56 84.19 84.19 24.10 891 246.43 904AL TP -7.56

72.22 94.97 16.01 25334 -9.85 14.57 VIC R4C -49.87 14.57 -49.87 94.97 18.54 181.21 955 248.37 35.34 PDMAKER1 -7.60 246.43 176.82 35.53 14.40 246.74 893 72LH8 -7.48

72RV6 72RV4 72RV2 0.00 71.89 -7.49 40.68 908 TP Total Victoria Load: 140.00 MW -10.57 211.24

43.22 95.07 217.89 71.76 -11.42 18.56

507 71.86 1.05 133 255.38 248.68 ROSSDALE -11.39

WABAMUN4 -3.61 71.11 118.74 29.40 42.39 29.45 42.46 22.44 32.35 -7.39 181.61 57.11 0.00 0.00 0.00 0.00

37.76 37.76 205.78 147.47 147.47

64.45 40.18 342.12 260.40 -1.40 43.21 44.72 218.07 51.85 54.44513 346.99 43.20 902L LAMBTON4 64.11 1 1 542 LAMBTON8 262.56 255.74 0.971810.97181 50.31 51.32 764 246.68 1058JOIN -7.34 205.87 40.15 157.90 223.68 31.69 506 247.92 BELLAMY4 -6.82 34.66 205.87 150.51 38.85 42.86 150.51 0.00 38.85 0.00 505 JASPER 4 0.00 0.00 248.15

135 34.43 38.76 -6.51 SUNDANC4 142.26 160.17 206.41 509 248.08 518 248.03 34.55 ARGYLL W -6.75 ARGYLL E -6.73 157.52 133.28 32.24 38.10

248.48 270.00 -6.43 36.38 30.77 43.96 157.52 255.60 133.28 1.64 158.85 133.35 511 SUMMERS1 31.90 30.74

391.76 382.91 26.08 49.18 49.44 4.99 512 DOME 4 420 121.21 KEEPHIL4 521 23.47 PETROLIA

220.08 44.19 128 248.18 ELLERSLI -6.49 165.64 270.02 43.96 211.91 40.57 497 14.37 121.30 23.52 27.66 5.30 157.65 36.39 209.01 40.93 32.49 ROSS 8 -41.39 248.50 -6.30

2017SP AESO Bus - Base voltage (kV) LOSS OF 72RG7 (ROSSDALE TO GARNEAU) Branch - MVA/% Rate A FIG A-3 Equipment - MW/Mvar THU, NOV 03 2016 15:14 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 248.05 57 247.19 519 -9.09 4.01 LAMOURE4 26.10 17.38 5.17 112.48 38.28 -8.96 22.33 CASTLEDN 549 141.29 63 141.15 83.75 17.12 INLANDCT LAMOURE7-11.84 -10.43 165.21 72.31 530 -9.68 516 NAMAO 8 CLOVERB8 27.66 16.00 27.43 27.88 28.82 27.56 59.78 57.01

520 247.11 28.62 27.36 514 246.88 VICTORIA -9.12 CLOVERB4 -7.93 113.55 26.48 84.13 17.20 59.37 56.59 533 72VN21 528 366 141.08 VICTORIA KENNDALE 898 141.50 VISCOUNT -12.02 GENSTR T -11.73 72CN10 56.12 91.04 32.58 27.42 27.83 55.92 27.18 56.86 27.64 84.13 18.16 45.49 43.19 165.21 1 0.9783 26.70 1 9 1 5 6 76.09 71.48 . . 42.00 48.27 1 1 4 3 88.77 75.93 71.76 25337 57.07 25331

-9.98 VIC 1 0.98226 1 VIC R1 27.15 1

61.34 56.70 56.70 56.7053914.10 71.66 60.23 83.02 WOODCRF2 -11.55 88.39 83.97 56.01 56.01 3.90 150.78 0.98226 1 1 17.73 6 940 141.52 25335 . 5 1 N CALDE7. 4 -11.71 1 VIC R3 136 246.39 4 26.82 15.48 42.09 48.23 14.58 E EDMON4 -7.71

18.90 18.53 58.20 91.56 18.12 17.98 -49.88 72.52

66.68 45.76 45.76 24.10

196.11 -9.58 357 139.65 25333 STALBE7 -12.93 31.02 VIC R3C 41.12 35.40 70.11 13.69 87.85 76.14 535 71.81 208.47 1 GARNEAU8 -11.50 44.77 14.58 181.28 39.69 37.79 37.79 37.79 -49.88 502 57.19 54.90 91.53 91.53 HARDIST8 72CH11 72CH9 0.98 33.05 55.23 39.11 48.81 25338 785 246.32 32.07 VIC 2 14.86 1059A_TP -7.63 46.28 -47.04 70.42 13.75 18.90 18.53 9.50 62.52 201.39 68.13 165.44 38.31 25332 45.76 45.76 3.90 158.84 VIC R2 94.78 15.98 247.35 137 14.86 -47.04

-8.37 58.05 N CALDE4 35.59 23.50 178.80 176.39 61.73 57.06 57.06 57.06 58.20 33.92 88.96 84.51 84.14 84.14 24.10 891 246.33 904AL TP -7.57

71.46 94.85 15.99 25334 -10.12 14.58 VIC R4C -49.88 14.58 -49.88 94.85 18.53 181.37 955 248.33 35.38 PDMAKER1 -7.62 246.34 176.74 35.51 14.40 246.64 893 72LH8 -7.50

72RV6 72RV4 72RV2 0.00 71.86 -7.51 40.74 908 TP Total Victoria Load: 140.00 MW -10.58 211.46

43.21 94.95 217.80 71.79 -11.43 18.54

507 71.90 1.05 133 255.37 248.64 ROSSDALE -11.40

WABAMUN4 -3.62 32.52 54.27 38.23 47.65 29.68 42.77 29.73 42.84 22.65 32.64 -7.40 181.66 57.12 0.00 0.00 0.00 0.00

37.67 37.67 206.03 147.21 147.21

64.47 40.24 342.20 260.40 -1.42 43.22 44.72 217.97 51.87 54.46513 347.08 43.19 902L LAMBTON4 64.13 1 1 542 LAMBTON8 262.65 255.82 0.971810.97181 50.33 51.34 764 246.60 1058JOIN -7.35 206.12 40.22 157.97 223.87 31.70 506 247.88 BELLAMY4 -6.84 34.72 206.12 150.14 38.76 42.90 150.14 0.00 38.76 0.00 505 JASPER 4 0.00 0.00 248.09

135 34.42 38.65 -6.52 SUNDANC4 142.20 159.68 206.66 509 248.03 518 247.98 34.60 ARGYLL W -6.77 ARGYLL E -6.75 157.56 133.29 32.24 38.12

248.43 270.25 -6.45 36.39 30.78 44.01 157.56 255.60 133.29 1.63 158.93 133.35 511 SUMMERS1 31.92 30.75

391.89 382.99 26.88 49.19 49.46 5.14 512 DOME 4 420 121.32 KEEPHIL4 521 23.49 PETROLIA

220.25 44.23 128 248.11 ELLERSLI -6.51 165.80 270.27 44.01 212.13 40.63 497 14.38 121.41 23.54 28.53 5.46 157.70 36.41 209.23 40.98 32.53 ROSS 8 -41.40 248.44 -6.32

2017SP AESO Bus - Base voltage (kV) LOSS OF 72CH11 (CLOVERBAR TO HARDISTY) Branch - MVA/% Rate A FIG A-4 Equipment - MW/Mvar THU, NOV 03 2016 15:14 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 248.05 57 247.19 519 -9.09 4.01 LAMOURE4 26.10 17.38 5.17 112.48 38.28 -8.96 22.33 CASTLEDN 549 141.29 63 141.15 83.75 17.12 INLANDCT LAMOURE7-11.84 -10.43 165.21 72.31 530 -9.68 516 NAMAO 8 CLOVERB8 27.66 16.00 27.43 27.88 28.82 27.56 59.78 57.01

520 247.11 28.62 27.36 514 246.89 VICTORIA -9.12 CLOVERB4 -7.93 113.55 26.47 84.13 17.20 59.37 56.59 533 72VN21 528 366 141.08 VICTORIA KENNDALE 898 141.50 VISCOUNT -12.02 GENSTR T -11.73 72CN10 56.13 91.07 32.58 27.42 27.83 55.93 27.19 56.87 27.64 84.13 18.16 45.49 43.19 165.21 1 0.9783 26.70 1 9 1 5 6 76.09 71.48 . . 42.00 48.28 1 1 4 3 88.77 75.93 71.76 25337 57.08 25331

-9.98 VIC 1 0.98226 1 VIC R1 27.15 1

61.34 56.70 56.70 56.7053914.10 71.66 83.02 WOODCRF2 -11.55 88.39 83.97 56.01 56.01 3.90 0.98226 1 1 17.73 6 940 141.52 25335 . 5 1 N CALDE7. 4 -11.71 60.21 1 VIC R3 136 246.39 4 26.82 15.48 42.09 48.23 14.58 150.73 E EDMON4 -7.72

18.90 18.53 58.20 91.58 18.12 17.99 -49.88 72.52

66.68 45.76 45.76 24.10

196.11 -9.58 357 139.65 25333 STALBE7 -12.93 31.02 VIC R3C 41.12 35.40 70.11 13.69 87.85 76.14 535 71.81 208.47 1 GARNEAU8 -11.50 44.77 14.58 181.28 39.69 37.79 37.79 37.79 -49.88 502 57.19 54.90 91.53 91.53 HARDIST8 72CH11 72CH9 0.98 33.05 55.23 39.11 48.81 25338 62.52 785 246.32 32.07 VIC 2 14.86 158.87 1059A_TP -7.63 46.28 -47.04 70.43 13.76 18.90 18.53 9.50 201.39 68.13 165.45 38.31 25332 45.76 45.76 3.90 VIC R2 94.78 15.98 247.35 137 14.86 -47.04

-8.37 58.05 N CALDE4 35.59 23.50 178.80 176.40 61.73 57.06 57.06 57.06 58.20 33.92 88.95 84.51 84.14 84.14 24.10 891 246.33 904AL TP -7.57

71.45 94.86 15.99 25334 -10.13 14.58 VIC R4C -49.88 14.58 -49.88 94.86 18.53 181.37 955 248.33 35.38 PDMAKER1 -7.62 246.34 176.74 35.51 14.40 246.64 893 72LH8 -7.50

72RV6 72RV4 72RV2 0.00 71.86 -7.51 40.74 908 TP Total Victoria Load: 140.00 MW -10.58 211.46

43.21 94.95 217.80 71.79 -11.43 18.54

507 71.90 1.05 133 255.37 248.64 ROSSDALE -11.40

WABAMUN4 -3.62 32.52 54.27 38.23 47.65 29.68 42.77 29.73 42.84 22.66 32.64 -7.40 181.66 57.12 0.00 0.00 0.00 0.00

37.67 37.67 206.03 147.21 147.21

64.47 40.24 342.20 260.40 -1.42 43.22 44.72 217.97 51.87 54.46513 347.07 43.19 902L LAMBTON4 64.13 1 1 542 LAMBTON8 262.65 255.81 0.971810.97181 50.33 51.34 764 246.60 1058JOIN -7.35 206.12 40.22 157.97 223.86 31.70 506 247.88 BELLAMY4 -6.84 34.72 206.12 150.14 38.76 42.90 150.14 0.00 38.76 0.00 505 JASPER 4 0.00 0.00 248.09

135 34.42 38.65 -6.53 SUNDANC4 142.19 159.68 206.66 509 248.03 518 247.98 34.60 ARGYLL W -6.77 ARGYLL E -6.75 157.56 133.28 32.24 38.12

248.43 270.25 -6.45 36.39 30.78 44.01 157.56 255.60 133.28 1.63 158.93 133.35 511 SUMMERS1 31.92 30.75

391.89 382.99 26.88 49.19 49.46 5.14 512 DOME 4 420 121.32 KEEPHIL4 521 23.49 PETROLIA

220.25 44.23 128 248.11 ELLERSLI -6.51 165.80 270.27 44.01 212.13 40.63 497 14.38 121.41 23.54 28.52 5.46 157.70 36.41 209.23 40.98 32.53 ROSS 8 -41.40 248.44 -6.32

2017SP AESO Bus - Base voltage (kV) LOSS OF 72CH9 (CLOVERBAR TO HARDISTY) Branch - MVA/% Rate A FIG A-5 Equipment - MW/Mvar THU, NOV 03 2016 15:14 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 248.12 57 247.25 519 -9.07 4.05 LAMOURE4 26.03 17.53 5.21 112.18 38.27 -8.94 22.50 CASTLEDN 549 141.32 63 141.18 83.77 17.12 INLANDCT LAMOURE7-11.82 -10.41 165.22 72.20 530 -9.76 516 NAMAO 8 CLOVERB8 27.67 16.00 27.43 27.88

520 247.16 57.45 56.35 514 247.00 VICTORIA -9.11 CLOVERB4 -7.92 113.23 26.39 84.09 17.19 119.36 116.35 533 72VN21 528 366 141.11 VICTORIA KENNDALE 898 141.53 VISCOUNT -12.00 GENSTR T -11.71 72CN10 56.45 92.29 32.54 27.42 27.82 56.18 27.29 57.12 27.75 84.09 18.15 45.49 43.18 165.10 1 0.9783 26.81 1 9 1 5 6 75.95 71.35 . . 42.02 48.30 1 1 3 3 88.77 75.92 71.88 25337 57.40 25331

-9.96 VIC 1 0.98226 1 VIC R1 27.26 1

61.34 56.70 56.70 56.7053914.10 71.68 29.02 82.99 WOODCRF2 -11.53 88.36 83.94 55.99 55.99 3.90 72.53 0.98226 1 1 17.72 6 940 141.55 25335 . 5 1 N CALDE7. 4 -11.69 28.66 1 VIC R3 136 246.48 3 26.83 15.48 42.12 48.25 14.58 71.62 E EDMON4 -7.70

18.89 18.53 58.20 92.81 18.36 18.22 -49.85 72.64

66.68 45.75 45.75 24.10

196.14 -9.56 357 139.68 25333 STALBE7 -12.92 31.05 VIC R3C 41.08 35.37 70.30 13.72 87.85 76.13 535 71.83 208.35 1 GARNEAU8 -11.48 44.79 14.58 181.19 39.68 37.79 37.79 37.79 -49.86 502 57.17 54.88 91.50 91.50 HARDIST8 72CH11 72CH9 0.98 33.05 55.21 39.11 48.79 25338 31.07 785 246.41 32.09 VIC 2 14.87 78.19 1059A_TP -7.62 46.30 -47.02 70.62 13.79 18.89 18.53 9.50 31.41 201.43 68.13 165.45 38.31 25332 45.75 45.75 3.90 79.04 VIC R2 94.84 15.99 247.40 137 14.87 -47.02

-8.36 58.01 N CALDE4 35.58 23.52 178.73 176.41 61.73 57.06 57.06 57.06 58.20 33.93 88.92 84.48 84.11 84.11 24.10 891 246.42 904AL TP -7.56

72.15 94.92 16.00 25334 -9.85 14.58 VIC R4C -49.85 14.58 -49.86 94.92 18.53 181.28 955 248.39 35.35 PDMAKER1 -7.61 246.43 176.75 35.51 14.40 246.73 893 72LH8 -7.48

72RV6 72RV4 72RV2 0.00 71.89 -7.50 40.70 908 TP Total Victoria Load: 140.00 MW -10.57 211.33

43.20 95.01 217.81 71.81 -11.41 18.55

507 71.92 1.05 133 255.38 248.70 ROSSDALE -11.38

WABAMUN4 -3.61 32.52 54.26 38.23 47.63 29.70 42.78 29.75 42.86 22.67 32.66 -7.39 181.58 57.09 0.00 0.00 0.00 0.00

37.66 37.66 205.89 147.21 147.21

64.44 40.20 342.07 260.40 -1.41 43.21 44.72 217.99 51.85 54.44513 346.94 43.18 902L LAMBTON4 64.10 1 1 542 LAMBTON8 262.52 255.70 0.971810.97181 50.31 51.31 764 246.68 1058JOIN -7.34 205.98 40.18 157.91 223.67 31.69 506 247.95 BELLAMY4 -6.82 34.68 205.98 150.13 38.75 42.86 150.13 0.00 38.75 0.00 505 JASPER 4 0.00 0.00 248.16

135 34.37 38.66 -6.51 SUNDANC4 142.04 159.76 206.52 509 248.10 518 248.05 34.57 ARGYLL W -6.75 ARGYLL E -6.73 157.56 133.22 32.22 38.11

248.49 270.11 -6.43 36.38 30.76 43.98 157.56 255.60 133.22 1.64 158.87 133.28 511 SUMMERS1 31.90 30.72

391.75 382.92 26.50 49.18 49.44 5.07 512 DOME 4 420 121.20 KEEPHIL4 521 23.47 PETROLIA

220.07 44.19 128 248.18 ELLERSLI -6.49 165.70 270.13 43.98 212.01 40.59 497 14.38 121.29 23.51 28.11 5.38 157.70 36.40 209.10 40.95 32.50 ROSS 8 -41.38 248.50 -6.30

2017SP AESO Bus - Base voltage (kV) LOSS OF 72CK12 (CLOVERBAR TO KENNEDALE) Branch - MVA/% Rate A FIG A-6 Equipment - MW/Mvar THU, NOV 03 2016 15:14 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 248.12 57 247.25 519 -9.07 4.05 LAMOURE4 26.03 17.53 5.21 112.18 38.27 -8.94 22.50 CASTLEDN 549 141.32 63 141.18 83.77 17.12 INLANDCT LAMOURE7-11.82 -10.41 165.22 72.20 530 -9.76 516 NAMAO 8 CLOVERB8 27.67 16.00 27.43 27.88 57.45 56.35 119.35 116.37 520 247.16 514 247.00 VICTORIA -9.11 CLOVERB4 -7.92 113.23 26.39 84.09 17.19 533 72VN21 528 366 141.11 VICTORIA KENNDALE 898 141.53 VISCOUNT -12.00 GENSTR T -11.71 72CN10 56.45 92.28 32.54 27.42 27.82 56.18 27.29 57.12 27.75 84.09 18.15 45.49 43.18 165.10 1 0.9783 26.81 1 9 1 5 6 75.95 71.35 . . 42.02 48.30 1 1 3 3 88.77 75.92 71.88 25337 57.39 25331

-9.96 VIC 1 0.98226 1 VIC R1 27.26 1

61.34 56.70 56.70 56.7053914.10 71.68 29.02 82.99 WOODCRF2 -11.53 88.36 83.94 55.99 55.99 3.90 72.53 0.98226 1 1 17.72 6 940 141.55 25335 . 5 1 N CALDE7. 4 -11.69 28.66 1 VIC R3 136 246.48 3 26.83 15.48 42.12 48.25 14.58 71.62 E EDMON4 -7.70

18.89 18.53 58.20 92.80 18.36 18.22 -49.85 72.64

66.68 45.75 45.75 24.10

196.14 -9.56 357 139.68 25333 STALBE7 -12.92 31.05 VIC R3C 41.08 35.37 70.30 13.72 87.85 76.13 535 71.83 208.35 1 GARNEAU8 -11.48 44.79 14.58 181.19 39.68 37.79 37.79 37.79 -49.86 502 57.17 54.88 91.50 91.50 HARDIST8 72CH11 72CH9 0.98 33.05 55.21 39.11 48.79 25338 31.07 785 246.41 32.09 VIC 2 14.87 78.19 1059A_TP -7.62 46.30 -47.02 70.62 13.79 18.89 18.53 9.50 31.41 201.42 68.13 165.45 38.31 25332 45.75 45.75 3.90 79.04 VIC R2 94.84 15.99 247.40 137 14.87 -47.02

-8.36 58.01 N CALDE4 35.58 23.52 178.73 176.41 61.73 57.06 57.06 57.06 58.20 33.93 88.92 84.48 84.11 84.11 24.10 891 246.42 904AL TP -7.56

72.15 94.92 16.00 25334 -9.85 14.58 VIC R4C -49.85 14.58 -49.86 94.92 18.53 181.28 955 248.39 35.35 PDMAKER1 -7.61 246.43 176.75 35.51 14.40 246.73 893 72LH8 -7.48

72RV6 72RV4 72RV2 0.00 71.89 -7.50 40.70 908 TP Total Victoria Load: 140.00 MW -10.57 211.33

43.20 95.01 217.81 71.81 -11.41 18.55

507 71.92 1.05 133 255.38 248.70 ROSSDALE -11.38

WABAMUN4 -3.61 32.52 54.26 38.23 47.63 29.70 42.78 29.75 42.86 22.67 32.66 -7.39 181.58 57.09 0.00 0.00 0.00 0.00

37.66 37.66 205.89 147.21 147.21

64.44 40.20 342.07 260.40 -1.41 43.21 44.72 217.99 51.85 54.44513 346.94 43.18 902L LAMBTON4 64.10 1 1 542 LAMBTON8 262.52 255.70 0.971810.97181 50.31 51.31 764 246.68 1058JOIN -7.34 205.98 40.18 157.91 223.67 31.69 506 247.95 BELLAMY4 -6.82 34.68 205.98 150.13 38.75 42.86 150.13 0.00 38.75 0.00 505 JASPER 4 0.00 0.00 248.16

135 34.37 38.66 -6.51 SUNDANC4 142.04 159.76 206.52 509 248.10 518 248.05 34.57 ARGYLL W -6.75 ARGYLL E -6.73 157.56 133.22 32.22 38.11

248.49 270.11 -6.43 36.38 30.76 43.98 157.56 255.60 133.22 1.64 158.87 133.28 511 SUMMERS1 31.90 30.72

391.75 382.92 26.50 49.18 49.44 5.07 512 DOME 4 420 121.20 KEEPHIL4 521 23.47 PETROLIA

220.07 44.19 128 248.18 ELLERSLI -6.49 165.70 270.13 43.98 212.01 40.59 497 14.38 121.29 23.51 28.11 5.38 157.70 36.40 209.10 40.95 32.50 ROSS 8 -41.38 248.50 -6.30

2017SP AESO Bus - Base voltage (kV) LOSS OF 72CK13 (CLOVERBAR TO KENNEDALE) Branch - MVA/% Rate A FIG A-7 Equipment - MW/Mvar THU, NOV 03 2016 15:14 100.0%Rate A

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 250.54 57 250.07 519 -7.39 2.80 LAMOURE4 14.59 23.13 3.52 30.66 18.27 -7.24 CASTLEDN 120.46 549 143.28 63 142.30 68.87 13.14 INLANDCT LAMOURE7-10.31 -8.66 159.34 72.26 530 -7.50 516 NAMAO 8 CLOVERB8 34.90 17.72 31.45 31.53 27.98 27.11 49.48 47.81

520 249.87 27.79 26.91 514 251.08 VICTORIA -7.37 CLOVERB4 -6.17 120.65 15.05 23.12 78.81 49.14 47.46 533 72VN21 528 366 143.05 VICTORIA KENNDALE 898 143.54 VISCOUNT -10.60 GENSTR T -10.20 72CN10 44.94 70.67 25.20 31.44 31.46 78.81 16.82 44.21 42.59 44.50 21.27 45.25 21.63 161.08 1 0.9783 21.40 1 7 1 8 8 73.96 70.57 . . 56.46 60.45 2 8 1 0 87.42 66.22 71.75 25337 45.70 25331 -7.82 VIC 1 1.0062 1 VIC R1 21.76 1

57.79 54.56 54.56 54.5653919.70 71.93 28.97 77.14 WOODCRF2 -9.39 1.0062 82.96 78.81 52.56 52.56 2.70 72.59 1 1 16.41 8 740 143.55 25335 . 8 8 N CALDE7. 1 -10.17 28.61 2 VIC R3 136 250.80 0 33.82 17.02 56.65 60.44 14.95 71.70 E EDMON4 -6.00

18.15 17.93 50.30 71.18 13.65 13.54 -47.52 72.45

69.29 43.17 43.17 16.70

206.73 -7.38 357 141.98 25333 STALBE7 -11.40 27.65 VIC R3C 39.50 73.37 14.08 34.43 86.65 66.36 535 72.10 205.88 1 GARNEAU8 -9.30 39.75 14.95 179.50 37.57 36.30 36.30 36.30 -47.52 502 53.94 51.78 86.33 86.33 HARDIST8 72CH11 72CH9 0.98 19.01 29.33 22.77 25.32 25338 30.37 785 250.72 28.57 VIC 2 15.13 76.58 1059A_TP -5.91 41.08 -44.80 73.70 14.14 18.15 17.93 19.70 30.70 211.83 70.80 159.56 30.66 25332 43.17 43.17 2.70 77.42 VIC R2 98.32 13.24 250.38 137 15.13 -44.80 -6.69 37.14 N CALDE4 37.66 21.00 169.30 195.97 58.16 54.91 54.91 54.91 50.30 30.20 83.49 79.31 78.97 78.97 16.70 891 250.73 904AL TP -5.85

72.00 98.41 13.25 25334 -7.70 14.95 VIC R4C -47.52 14.95 -47.52 98.41 18.88 179.60 955 251.84 34.43 PDMAKER1 -5.91 250.72 196.52 37.54 14.40 250.97 893 0.00 72LH8 -5.78 72RV6 72RV4 72RV2 72.00 -5.80 30.80 908 TP Total Victoria Load: 140.00 MW -8.43 208.73

37.19 98.53 233.74 72.06 -9.29 18.91 507 72.13 133 256.07

252.23 ROSSDALE -9.23 1.0239

WABAMUN4 -2.13 19.58 30.20 22.60 25.13 27.21 39.08 27.30 39.21 20.71 29.74 -5.68 171.41 36.77 0.00 0.00 0.00 0.00 28.46 28.46 200.38 128.53 128.53

64.27 38.45 342.06 260.40 0.14 37.33 38.27 233.97 44.72 45.79513 346.38 37.16 902L LAMBTON4 64.00 1 1 542 LAMBTON8 247.79 242.71 1.00921.0092 39.30 39.74 764 250.91 1058JOIN -5.63 200.45 38.44 157.91 207.03 25.85 506 252.30 BELLAMY4 -5.11 26.97 200.45 128.06 0.00 28.20 0.00 32.84 128.06 28.20 505 JASPER 4 0.00 0.00 252.02

135 23.74 27.68 -4.83 SUNDANC4 119.54 139.36 200.92 509 252.35 518 252.26 26.92 ARGYLL W -5.05 ARGYLL E -5.03 149.86 120.32 23.89 29.76

252.31 272.87 -4.76 27.58 22.13 36.45 149.86 255.60 120.32 3.05 158.73 120.51 511 SUMMERS1 25.98 22.17

377.01 372.37 24.95 47.33 47.35 3.66 512 DOME 4 420 118.89 KEEPHIL4 521 22.67 PETROLIA

204.46 33.48 128 252.03 ELLERSLI -4.81 209.35 30.76 161.69 272.88 36.45 497 14.43 118.90 22.69 26.56 3.90 150.16 27.66 206.60 39.44 25.20 ROSS 8 -39.23 252.25 -4.63

2017WP AESO Bus - Base voltage (kV) BASE CASE (N-0) Branch - MVA/% Rate B FIG A-1 Equipment - MW/Mvar WED, NOV 16 2016 10:45 100.0%Rate B

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 250.44 57 249.98 519 -7.41 2.77 LAMOURE4 14.43 23.13 3.47 30.67 18.03 -7.25 CASTLEDN 120.38 549 143.24 63 142.25 68.86 13.14 INLANDCT LAMOURE7-10.33 -8.68 159.35 72.06 530 -7.52 516 NAMAO 8 CLOVERB8 34.90 17.73 31.45 31.54 27.99 27.12 49.63 47.96

520 249.78 27.79 26.92 514 250.89 VICTORIA -7.39 CLOVERB4 -6.19 120.61 15.07 23.13 78.87 49.29 47.60 533 72VN21 528 366 143.01 VICTORIA KENNDALE 898 143.49 VISCOUNT -10.62 GENSTR T -10.22 72CN10 43.45 69.19 25.23 31.44 31.47 78.87 16.84 44.21 42.61 43.11 20.62 43.84 20.97 161.20 1 0.9783 20.75 1 7 1 8 8 74.17 70.78 . . 56.42 60.42 2 7 3 9 87.41 66.23 71.55 25337 44.18 25331 -7.85 VIC 1 1.0062 1 VIC R1 21.10 1

57.79 54.56 54.56 54.5653919.70 71.90 59.37 77.20 WOODCRF2 -9.41 1.0062 83.00 78.85 52.59 52.59 2.70 149.19 1 1 16.43 8 740 143.51 25335 . 8 8 N CALDE7. 0 -10.19 2 VIC R3 136 250.65 2 33.82 17.03 56.61 60.41 14.94 E EDMON4 -6.01

18.15 17.93 50.30 69.65 13.37 13.27 -47.55 72.25

69.30 43.19 43.19 16.70

206.68 -7.40 357 141.93 25333 STALBE7 -11.42 27.64 VIC R3C 39.54 73.04 14.02 34.47 86.64 66.37 535 72.07 205.98 1 GARNEAU8 -9.32 39.75 14.94 179.55 37.58 36.30 36.30 36.30 -47.55 502 53.97 51.81 86.38 86.38 HARDIST8 72CH11 72CH9 0.98 19.01 29.34 22.77 25.34 25338 785 250.58 28.56 VIC 2 15.13 1059A_TP -5.93 41.08 -44.82 73.37 14.09 18.15 17.93 19.70 61.10 211.78 70.80 159.58 30.67 25332 43.19 43.19 2.70 155.67 VIC R2 98.18 13.23 250.30 137 15.13 -44.83 -6.71 37.17 N CALDE4 37.66 20.99 169.37 195.94 58.16 54.91 54.91 54.91 50.30 30.20 83.53 79.35 79.00 79.00 16.70 891 250.59 904AL TP -5.87

71.26 98.27 13.24 25334 -7.99 14.94 VIC R4C -47.55 14.94 -47.55 98.27 18.87 179.65 955 251.75 34.46 PDMAKER1 -5.93 250.58 196.49 37.55 14.40 250.83 893 0.00 72LH8 -5.79 72RV6 72RV4 72RV2 71.96 -5.81 30.83 908 TP Total Victoria Load: 140.00 MW -8.45 208.84

37.19 98.38 233.71 72.03 -9.31 18.89 507 72.10 133 256.05

252.15 ROSSDALE -9.25 1.0239

WABAMUN4 -2.15 19.58 30.21 22.60 25.14 27.20 39.09 27.29 39.21 20.70 29.75 -5.70 171.49 36.79 0.00 0.00 0.00 0.00 28.47 28.47 200.52 128.53 128.53

64.30 38.50 342.22 260.40 0.12 37.33 38.27 233.94 44.75 45.82513 346.56 37.17 902L LAMBTON4 64.03 1 1 542 LAMBTON8 247.92 242.81 1.00921.0092 39.32 39.77 764 250.78 1058JOIN -5.65 200.60 38.49 157.97 207.21 25.87 506 252.19 BELLAMY4 -5.13 27.01 200.60 128.06 0.00 28.21 0.00 32.87 128.06 28.21 505 JASPER 4 0.00 0.00 251.90

135 23.77 27.70 -4.85 SUNDANC4 119.65 139.43 201.07 509 252.24 518 252.15 26.95 ARGYLL W -5.07 ARGYLL E -5.05 150.06 120.23 23.88 29.82

252.21 273.02 -4.77 27.63 22.13 36.49 150.06 255.60 120.23 3.03 158.80 120.41 511 SUMMERS1 26.00 22.16

377.11 372.38 25.57 47.34 47.37 3.75 512 DOME 4 420 118.98 KEEPHIL4 521 22.69 PETROLIA

204.64 33.53 128 251.92 ELLERSLI -4.83 209.46 30.79 161.78 273.03 36.49 497 14.42 118.99 22.72 27.23 4.00 150.36 27.71 206.70 39.48 25.22 ROSS 8 -39.25 252.14 -4.64

2017WP AESO Bus - Base voltage (kV) LOSS OF 72CH11 (CLOVERBAR TO HARDISTY) Branch - MVA/% Rate B FIG A-2 Equipment - MW/Mvar WED, NOV 16 2016 10:46 100.0%Rate B

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 250.44 57 249.98 519 -7.41 2.77 LAMOURE4 14.43 23.13 3.47 30.67 18.03 -7.26 CASTLEDN 120.38 549 143.24 63 142.25 68.86 13.14 INLANDCT LAMOURE7-10.33 -8.68 159.35 72.06 530 -7.52 516 NAMAO 8 CLOVERB8 34.90 17.73 31.45 31.54 27.99 27.12 49.63 47.95

520 249.78 27.79 26.92 514 250.89 VICTORIA -7.39 CLOVERB4 -6.19 120.61 15.07 23.13 78.87 49.28 47.60 533 72VN21 528 366 143.01 VICTORIA KENNDALE 898 143.49 VISCOUNT -10.62 GENSTR T -10.22 72CN10 43.47 69.21 25.23 31.44 31.47 78.87 16.84 44.21 42.61 43.13 20.63 43.85 20.97 161.20 1 0.9783 20.76 1 7 1 8 8 74.17 70.78 . . 56.42 60.42 2 7 2 9 87.41 66.23 71.55 25337 44.20 25331 -7.85 VIC 1 1.0062 1 VIC R1 21.10 1

57.79 54.56 54.56 54.5653919.70 71.90 77.20 WOODCRF2 -9.41 1.0062 83.00 78.85 52.59 52.59 2.70 1 1 16.43 8 740 143.51 25335 . 8 8 N CALDE7. 0 -10.19 59.36 2 VIC R3 136 250.65 2 33.82 17.03 56.61 60.41 14.94 149.15 E EDMON4 -6.01

18.15 17.93 50.30 69.66 13.37 13.27 -47.55 72.26

69.30 43.19 43.19 16.70

206.68 -7.40 357 141.93 25333 STALBE7 -11.42 27.64 VIC R3C 39.54 73.05 14.02 34.47 86.64 66.37 535 72.07 205.98 1 GARNEAU8 -9.32 39.75 14.94 179.56 37.58 36.30 36.30 36.30 -47.55 502 53.97 51.81 86.38 86.38 HARDIST8 72CH11 72CH9 0.98 19.01 29.34 22.77 25.34 25338 61.10 785 250.58 28.56 VIC 2 15.13 155.69 1059A_TP -5.93 41.08 -44.82 73.37 14.09 18.15 17.93 19.70 211.78 70.80 159.58 30.67 25332 43.19 43.19 2.70 VIC R2 98.18 13.23 250.30 137 15.13 -44.83 -6.71 37.17 N CALDE4 37.66 20.99 169.37 195.94 58.16 54.91 54.91 54.91 50.30 30.20 83.53 79.35 79.00 79.00 16.70 891 250.59 904AL TP -5.87

71.25 98.27 13.24 25334 -8.00 14.94 VIC R4C -47.55 14.94 -47.55 98.27 18.87 179.66 955 251.75 34.46 PDMAKER1 -5.93 250.59 196.49 37.55 14.40 250.83 893 0.00 72LH8 -5.79 72RV6 72RV4 72RV2 71.96 -5.81 30.83 908 TP Total Victoria Load: 140.00 MW -8.45 208.84

37.19 98.38 233.71 72.03 -9.31 18.89 507 72.10 133 256.05

252.15 ROSSDALE -9.26 1.0239

WABAMUN4 -2.15 19.58 30.21 22.60 25.14 27.20 39.09 27.29 39.21 20.70 29.75 -5.70 171.49 36.79 0.00 0.00 0.00 0.00 28.47 28.47 200.52 128.53 128.53

64.30 38.50 342.22 260.40 0.12 37.33 38.27 233.94 44.75 45.82513 346.56 37.17 902L LAMBTON4 64.03 1 1 542 LAMBTON8 247.92 242.81 1.00921.0092 39.32 39.77 764 250.78 1058JOIN -5.65 200.60 38.49 157.96 207.21 25.87 506 252.19 BELLAMY4 -5.13 27.01 200.60 128.06 0.00 28.21 0.00 32.87 128.06 28.21 505 JASPER 4 0.00 0.00 251.91

135 23.77 27.70 -4.85 SUNDANC4 119.65 139.43 201.07 509 252.24 518 252.15 26.95 ARGYLL W -5.07 ARGYLL E -5.05 150.05 120.23 23.88 29.82

252.21 273.02 -4.78 27.63 22.13 36.49 150.05 255.60 120.23 3.03 158.79 120.42 511 SUMMERS1 26.00 22.16

377.11 372.38 25.56 47.34 47.37 3.75 512 DOME 4 420 118.98 KEEPHIL4 521 22.69 PETROLIA

204.64 33.53 128 251.92 ELLERSLI -4.83 209.46 30.79 161.78 273.03 36.49 497 14.42 118.99 22.72 27.23 4.00 150.36 27.71 206.70 39.48 25.22 ROSS 8 -39.26 252.15 -4.64

2017WP AESO Bus - Base voltage (kV) LOSS OF 72CH9 (CLOVERBAR TO HARDISTY) Branch - MVA/% Rate B FIG A-3 Equipment - MW/Mvar WED, NOV 16 2016 10:46 100.0%Rate B

kV: <=25.000 <=69.000 <=138.000 <=240.000 <=500.000 >500.000

1 Attachment C

Post-Project Voltage Stability Diagrams (Scenarios 3 and 4)

November 2016 AESO 2016 PBCS - 2018SP: Base Case

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018SP: Contingency CBT2

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018SP: Contingency 240CV5

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018SP: Contingency VIC-T5

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018SP: Contingency CBT1

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018SP: Contingency 902L

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018WP: Base Case

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018WP: Contingency CBT2

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018WP: Contingency 240CV5

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018WP: Contingency VIC-T5

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018WP: Contingency CBT1

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000 AESO 2016 PBCS - 2018WP: Contingency 902L

1.20

1.00

0.80

0.60

0.40

0.20

0.00

-0.20 0 100 200 300 400 500 600 700 800 900 1000

Mark Bus 502 HARDIST8 69.000 507 ROSSDALE 69.000 516 CLOVERB8 69.000 520 VICTORIA 240.00 533 VICTORIA 69.000