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Appendix B Engineering Study NaturEner Canada
Appendix B Engineering Study NaturEner Canada Wild Rose 1 & 2 Wind Project Project Numbers: 479,693 Date: October 25, 2010 Name Signature Date Anuradha Dissanayaka October 25, 2010 Andrew Isaacs P.Eng. October 25, 2010 See "Responsibilities, Signature, and Seal" Chapter for Engineering Seal APEGGA Permit to Practice P-10922 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table of Contents 1.0 Connection Description ................................................................................. 4 2.0 Criteria and Assumptions .............................................................................. 5 2.1 2.2 2.3 2.4 2.5 Reliability Criteria ............................................................................................................. 5 AESO Load Assumptions................................................................................................... 6 Generation and Dispatch Assumptions............................................................................ 6 Facility Ratings.................................................................................................................. 9 Transmission Assumptions ............................................................................................. 10 2.5.1 2.5.2 2.5.3 2.5.4 2.5.5 2.5.6 2.5.7 2.5.8 3.0 Monitored Elements ........................................................................................................... 14 Generation Balancing ......................................................................................................... 15 Wind Farm Model ............................................................................................................... 16 LVRT and Reactive Power Criteria ...................................................................................... 16 SATR Transmission Assumptions ........................................................................................ 17 Additional Transmission Assumptions ................................................................................ 17 Additional Stability Analysis Assumptions, Observations, and Recommendations ........... 17 Special Wind Farm Considerations for Short Circuit Analysis............................................. 19 Existing System Assessment - 2012 Cases ................................................... 20 3.1 Powerflow Analysis ........................................................................................................ 20 3.1.1 3.1.3 3.1.4 3.2 Stability Analysis ............................................................................................................. 27 3.2.1 3.2.2 3.2.3 3.2.4 3.3 4.0 Existing System Powerflow Analysis Summary ................................................................... 20 2012 Summer Light Cases – Existing System ...................................................................... 21 2012 Summer Peak Cases – Existing System ...................................................................... 23 Existing System Dynamic Analysis Summary ...................................................................... 27 Contingency Description Existing System Cases ................................................................. 28 2012 Summer Light Cases – Existing System ...................................................................... 29 2012 Summer Peak Cases – Existing System ...................................................................... 30 Short Circuit Analysis - Existing System.......................................................................... 31 Proposed Connection Scenarios .................................................................. 32 4.1 4.2 5.0 Alternative 1 - Concept # 1 Wild Rose wind farm connection ....................................... 33 Alternative 2 - Concept # 2 Wild Rose Wind Farm connection..................................... 35 Evaluation of Proposed Connection ............................................................ 37 5.1 Powerflow Analysis ........................................................................................................ 37 5.1.1 5.1.2 5.1.3 5.1.4 5.1.5 5.1.6 5.1.7 5.2 Powerflow Analysis Summary (2012 Pre-SATR) ................................................................. 37 2012 Summer Light Cases ................................................................................................... 38 2012 Summer Peak Cases ................................................................................................... 45 Powerflow Analysis Summary (2013 SATR) ........................................................................ 51 Special Notes and Assumptions for 2013 Cases ................................................................. 52 2013 Summer Cases............................................................................................................ 53 Reactor Design .................................................................................................................... 57 Stability Analysis ............................................................................................................. 60 Alberta Electric System Operator 479,693 2 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.2.1 5.2.2 5.2.3 5.2.4 5.3 Short Circuit Analysis - Wind added System .................................................................. 67 5.3.1 5.3.2 6.0 Stability Analysis Summary ................................................................................................. 60 Contingency description ..................................................................................................... 62 2012 (Pre-SATR) Cases ........................................................................................................ 63 2013 (SATR) Cases............................................................................................................... 65 Short Circuit Analysis Results – 2012 (Pre-SATR)................................................................ 67 Short Circuit Analysis Results – 2013 (SATR) ...................................................................... 68 Summary and Conclusions .......................................................................... 69 6.1 Summary - Powerflow Analysis ...................................................................................... 69 6.1.1 6.1.2 6.1.3 6.2 Summary - Stability Analysis .......................................................................................... 72 6.2.1 6.3 6.4 7.0 Local Violations ................................................................................................................... 69 Remote Violations............................................................................................................... 70 System-Wide Concerns ....................................................................................................... 70 Results and Observations ................................................................................................... 72 Summary - Short Circuit Analysis ................................................................................... 74 Conclusions..................................................................................................................... 74 Responsibilities, Signature and Seal ............................................................ 75 Appendices ........................................................................................................... 76 Appendix A: Single Line Diagrams .................................................................... 77 Appendix B: Category C Powerflow Contingency Analysis ............................. 164 Appendix C: Acciona DYR model invocation................................................... 185 Appendix D: Dynamic Analysis Traces ............................................................ 186 Alberta Electric System Operator 479,693 3 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 1.0 Connection Description NaturEner Energy Canada Inc, through its project companies NaturEner Wild Rose 1 Energy Inc. and NaturEner Wild Rose 2 Energy Inc. (jointly referred to as NEC) is proposing to develop two wind-powered generation projects, Wild Rose 1 and Wild Rose 2, collectively the Wild Rose Wind Power Projects (WRWPP). The Nominal capacity of each plant is 200 MW. This study assumes 204 MW of generation using 136 – 1.5MW wind turbine generators for each project. Wild Rose 1 is located approximately 55 km southeast of the City of Medicine Hat and Wild Rose 2 is located and is approximately 30 km south of Medicine Hat. NEC plans to connect WRWPP generators to a collector substation they will construct to transform the voltage from 34.5 kV to 240 kV. Two conceptual connection alternatives were developed for study (named Concept 1 and Concept 2, described in detail in Chapter 4.0). These alternatives differed primarily in configuration of the lines connecting Wild Rose 1 and Wild Rose 2 together and to the Elkwater and Bowmanton Substations. Concept 1 has been removed from consideration by NEC, and all analysis in this report refers to Concept 2 only. Figure 1-1 Wild Rose 1 and 2 interconnection with SATR (ref. Section 2.5.5) Alberta Electric System Operator 479,693 4 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 2.0 Criteria and Assumptions The analysis for the connection of the Wild Rose Wind Power Project has been conducted based upon both 2012 and 2013 summer light and summer peak cases, using PSS/E’s contingency processor version 30.3.3. The following criteria and assumptions have been used for the analysis. 2.1 Reliability Criteria The voltage criteria are based on the AESO Transmission Reliability Criteria Part II (System Planning – dated March 11, 2005), as shown in Table 2‐1 and Table 2‐2 and was applied for N‐1 or Category B disturbances. Loading levels above 100 percent of Summer MVA rating (‘A’ Rating in PSS/E) were reported for all cases. Table 2‐1 illustrates the AESO planning criteria for steady state voltages. The “Extreme” values in this table were applied under contingency conditions, and the “Normal” values in the table were applied under normal conditions. Based on AESO screening suggestions during the preliminary studies, a more relaxed voltage magnitude criteria of 0.95 to 1.1 pu was applied to eliminate nuisance violations at the 240 kV level. Additionally, at the 138 kV level, the voltage magnitude criteria was tightened from the values in Table 2‐1 to 0.95 to 1.08 pu. The minimum contingency case voltage change for range violations to be reported is 0.01 pu. Table 2‐1 AESO Acceptable Range of Steady State Voltage Criteria Alberta Electric System Operator 479,693 5 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 2‐2 AESO Voltage Deviation Criteria 2.2 AESO Load Assumptions The study area loads modeled in the 2012 and 2013 summer light and summer peak load scenarios as provided by the AESO are listed in Table 2‐3. Table 2‐3 Study area load profile (2012 and 2013) 2012 2013 Base Case Summer Light (MW) Summer Peak (MW) Summer Light (MW) Study Area Total 768 1066 792 Summer Peak (MW) 1226 2.3 Generation and Dispatch Assumptions The generation facilities in the Hanna Area were dispatched as shown in Table 2‐4 and Table 2‐5 for the 2012 and 2013 cases. The wind interest in the south system was modeled as shown in Table 2‐6. The initial 2012 case analysis for the area was performed with existing area generation set at maximum levels. The addition of the wind generation projects in the south system with the maximum generation levels listed in Table 2‐5 Hanna Region generation and dispatch assumptions created significant overloads under system normal conditions. Due to these overloads, the dispatch levels for the existing generators in the 2012 cases were reduced to ease these overloads, primarily on the Red Deer to Nevis (912L) transmission line and allow the impact of full output of the Wild Rose Power Projects to be reviewed. This is an important assumption, since the Red Deer to Nevis line will overload if the generation in the south area of the system as represented in this study is at full power with the load levels and system ratings as modeled herein. These dispatch levels were adjusted to eliminate the Red Deer – Nevis overload during system intact (N‐0) conditions for selected worst overloading base cases. Until such time as transmission reinforcements are in place, it is understood that the AESO will develop operational rules to manage potential system constraints as required. The load and topology considered for the 2013 cases allowed full output of the existing area generation units to be reestablished, indicating the importance of load and topology issues. Alberta Electric System Operator 479,693 6 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 2-4 2012 Hanna Region generation and dispatch assumptions. (Based on S2C2GGA) Station Service Name Location Dispatch (MW) Load (MW) Battle River 3 Battle River 757S 158 9.2 + 4.9 MVAR Battle River 4 Battle River 757S 156.5 9.2 + 4.9 MVAR Battle River 5 Battle River 757S 407 25.6 + 18 MVAR Sheerness 1 Sheerness 807S 275 17 + 7.5 MVAR Sheerness 2 Sheerness 807S 275 17 + 7.5 MVAR Total Generation 1271.5 Wind Generation IP-518 81 IP-634 88 Total - Wind 169 Table 2-5 2013 Hanna Region generation and dispatch assumptions. (Based on S8C2GGA) Station Service Name Location Dispatch (MW) Load (MW) Battle River 3 Battle River 757S 158 9.2 + 4.9 MVAR Battle River 4 Battle River 757S 156.5 9.2 + 4.9 MVAR Battle River 5 Battle River 757S 407 25.6 + 18 MVAR Sheerness 1 Sheerness 807S 408 17 + 7.5 MVAR Sheerness 2 Sheerness 807S 408 17 + 7.5 MVAR Total Generation 1537.5 Wind Generation IP-518 81 IP-634 88 Total - Wind 169 Alberta Electric System Operator 479,693 7 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 2-6 Wind interest in the South system SATR Wind Interest Region 2012 base case Dispatch (MW) 2013 base case Dispatch (MW) Goose Lake Peigan MATL Blackie Vulcan Sub A Sub B Sub C Sub D (Whitla) Med Hat IP-513 Cypress IP-617 Wild Rose 1 IP-479 356 356 137 137 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 200 (modeled by Electranix) 200 (modeled by Electranix) Wild Rose 2 IP-693 200 (modeled by Electranix) 200 (modeled by Electranix) Total Wind Interest in South 893 893 Alberta Electric System Operator 479,693 8 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 2.4 Facility Ratings Table 2-7 provides the ratings of the transmission lines near the Wild Rose Wind Power Facility. Table 2-7 Transmission Line Ratings Burdet 368S Voltage (kV) 138 Rate A (MVA) 85 Rate B (MVA) 90 Rate C (MVA) 99 Taber 83S 138 85 90 99 Langdon 102S Milo Junction 356S 240 609 609 697 Lethbridge 370S Milo Junction 356S 240 481 481 529 Ware Junction 132S Jenner 275S 240 550 679 815 Line From To 612L Finacastle 336S 610L Finacastle 336S 923L/924L 923L/924L 944L/951L 931L Ware Junction 132S West Borok 28S 240 592 592 592 9L950/9L934 Ware Junction 132S Anderson 801S 240 519 663 663 814L/827L West Brrok 28S Brooks 121S 138 167 191 191 795L Hays 421S Brooks 121S 138 119 119 119 1002L Jenner 275S Dome Empress 163S 240 550 679 815 945L Jenner 275S Cypress 562S 240 550 679 815 760L Empress A7 394S Dome Empress 163S 138 119 146 161 669L Empress A7 394S Cypress 562S 138 90 110 121 1011L Cypress 562S Dome Empress 163S 138 177 191 210 879L 100L 892L Burdet 368S Suffile 895S Suffile 895S East Medicine Hat 41S Tilly 498S East Medicine Hat 41S 138 138 138 85 69 67 90 115 96 99 127 106 763L Taber 83S Vauxhal 158S 138 121 107 118 172L Taber 83S Chinchute 315S 138 119 146 161 821L Vauxhal 158S Hays 421S 138 85 90 99 763L Vauxhal 158S Ench tap 138 121 92 101 100L Tilly 498S West Borok 28S 138 96 96 106 853L West Brrok 28S Bassano Tap 138 121 148 163 763L West Brrok 28S Ench tap 138 117 89 98 923L/924L Milo Junction 356S West Borok 28S 240 599 599 599 924L Milo Junction 356S MATLB 240 481 499 599 138 90 96 106 760L East Medicine Hat 41S Chappice Lake 649S 760L Glendridge Chappice Lake 649S 138 90 110 121 853L Queens Town 504S Basano Tap 138 121 148 163 1034L/1035L West Brrok 28S Bowmanton 244S 240 1000 1200 1440 933L West Brrok 28S Anderson 801S 240 519 592 599 830L Cypress 562S MaCneil 840S 138 177 191 210 760L Glendridge Cypress 562S 138 90 110 121 978L Elkwater 264S Wild Rose 1 547S 240 492 606 606 1076L Elkwater 264S Eagle Butte 274S 240 492 606 606 1073L/1074L Elkwater 264S Bowmanton 244S 240 1000 1200 1440 1009L 964L/983L Cypress 562S Elkwater 264S Bowmanton 244S Witla 251S 240 240 638 1000 788 1200 788 1440 Alberta Electric System Operator 479,693 9 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 2.5 Transmission Assumptions 41 base cases were initially prepared according to the AESO requirements both in 2012 and 2013 summer light and summer peak cases. These base cases were developed according to the conceptual configurations set out jointly by AESO and NEC, showing both varying dispatch and load levels, and alternate connection configurations proposed by NEC and AltaLink. Medicine Hat import/export levels were fixed to 50MW export in summer light cases and 26MW import in summer peak. During the course of the study, one of the two connection alternatives was dropped from the analysis and 21 base cases were selected for further studies (identified as “concept 2”). Wild Rose 1 and Wild Rose 2 wind farms were added to the models, and the final base case list is shown in Table 2-8 and Table 2-9. Table 2-8 Cases for Powerflow and Dynamic Analysis 2012 Base Case Description 2012 Concept 2 Base Case Import from Saskatchewan (Export is -ve) Import from BC(Export is -ve) Medicine Hat Export Wild Rose 1 Wind Wild Rose 2 Wind Case Designation Concept #2 Existing System Cases 2012SL 2012SP 0MW -200MW 50MW 0MW 0MW S1C2ES 150MW -200MW 50MW 0MW 0MW S2C2ES -150MW -200MW 50MW 0MW 0MW S3C2ES 0MW -100MW -26MW 0MW 0MW S4C2ES 150MW -100MW -26MW 0MW 0MW S5C2ES -150MW -100MW -26MW 0MW 0MW S6C2ES WR1 2012SL 2012SP 0MW -200MW 50MW 200MW 0MW S1C2GA 150MW -200MW 50MW 200MW 0MW S2C2GA -150MW -200MW 50MW 200MW 0MW S3C2GA 0MW -100MW -26MW 200MW 0MW S4C2GA 150MW -100MW -26MW 200MW 0MW S5C2GA -150MW -100MW -26MW 200MW 0MW S6C2GA WR1+WR2 2012SL 2012SP 0MW -200MW 50MW 200MW 200MW S1C2GGA 150MW -200MW 50MW 200MW 200MW S2C2GGA -150MW -200MW 50MW 200MW 200MW S3C2GGA 0MW -100MW -26MW 200MW 200MW S4C2GGA 150MW -100MW -26MW 200MW 200MW S5C2GGA -150MW -100MW -26MW 200MW 200MW S6C2GGA Alberta Electric System Operator 479,693 10 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 2-9 Cases for Powerflow and Dynamic Analysis 2013 Base Case Description 2013 Base Case Import from Saskatchewan (Export is -ve) Import from BC(Export is -ve) Medicine Hat Export Wild Rose 1 Wind Wild Rose 2 Wind Case Designation Concept #2 WR1 + WR2 2013SL 0MW -200MW 50MW 200MW 200MW S8C2GGA 2013SP 0MW -100MW -26MW 200MW 200MW S9C2GGA 2013SP 150MW -100MW -26MW 200MW 200MW S10C2GGA The network configuration diagrams of the Wild Rose connection for 2012 and 2013 cases are shown in Figure 2-2 and Figure 2-3. Alberta Electric System Operator 479,693 11 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 138 kV existing in base case Amoco Empress 163S 1002L 240 kV existing in base case 240 kV Wind Facilities 1011L 945L Jenner 275S To Ware 944L/951L Junction 132S Cypress 562S 669L 830L McNeil 840S 760L 75 km Single Circuit 100L Bowmanton East (Medicine Hat) 244S (B0) Chappice Lake 649S 47.2 km Medicine Hat 41S Double Circuit Elkwater 264S 1.0 km Single Circuit 172L 36.4km WR2 WR1 2012 (pre‐SATR): Concept 2 Figure 2‐2 2012 pre‐SATR Wild Rose connection Concept #2 Alberta Electric System Operator 479,693 12 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Amoco Empress 163S 138 kV existing in base case 1002L 240 kV existing in base case 240 kV Wind Facilities 1011L 945L Jenner 275S To Ware 944L/951L Junction 132S Cypress 562S 669L 830L McNeil 840S 1034L 760L 75 km 1035L Single Circuit 100L Bowmanton (East Medicine Hat) 244S (B0) Chappice Lake 649S 47.2 km Medicine Hat 41S Whitla 251S Double Circuit Elkwater 264S 1.0 km Double Circuit Single Circuit 172L 36.4km WR2 WR1 2013 (SATR): Concept 2 Figure 2‐3 2013 SATR Wild Rose connection Concept #2 Alberta Electric System Operator 479,693 13 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 2.5.1 Monitored Elements All elements (above 70 kV) within the following planning areas (Table 2-10) were analysed as a part of the contingency analysis to satisfy the requirements of the AESO Reliability Criteria. This list was prepared by Electranix and approved by the AESO, and includes all line and transformer thermal overloads and bus voltage violations (steady state and voltage deviation). The violations identified in remote places such as Keephills and Brazeau were neglected according to the AESO instructions as these areas are remote from this project and the violations not necessary for inclusion in this project analysis. Table 2-10 Monitored Areas for Powerflow Analysis Powerflow Contingency Analysis Monitored Areas Monitored Area Number Area Name Lines 48 4 47 43 52 54 45 50 Empress Medicine Hat Brooks Sheerness Vauxhall Lethbridge Strathmore/Blackie Backbone All Branches All Branches All Branches All Branches All Branches All Branches All Branches All Branches All branch outages (above 70 kV) within the following planning areas (Table 2-11) were analyzed and contingency screening was done to find the problematic contingencies. Only the contingencies (reported in Sections 3.0 and 5.0) associated with overloading of branches or voltage violations are reported. N-2 (Category C) contingencies have been run (Table 2-12), and are reported in Appendix B. Table 2-13 shows the set of monitored elements used in the dynamic analysis. Table 2-11 Outage Screening Areas for Powerflow Analysis (Category B) Powerflow Contingency Screening Area List Monitored Area Number Area Name Outages 48 4 47 43 52 54 45 50 Empress Medicine Hat Brooks Sheerness Vauxhall Lethbridge Strathmore/Blackie Backbone All Branches All Branches All Branches All Branches All Branches All Branches All Branches All Branches Alberta Electric System Operator 479,693 14 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 2-12 Selected N-2 (Category C) contingencies for Powerflow Analysis Contingency Reference # Elements Outage Fault Location (line end) Fault C17 945L/951L - from Cypress to Jenner 3LG Cypress 240kV Substation - 562S C18 944L - from Jenner to Ware Junction 3LG Ware Jct 240kV Substation -132S C19 9L950/9L934 - from Ware Junction to Anderson 3LG Anderson 240kV Substation -801S C20 9L950/9L934 - from Ware Junction to Anderson 3LG Ware Junction 240kV Substation - 132S C21 923L/924L - from W. Brook to N.Lethbridge (Milo for 2013 cases) 3LG West Brooks 240kV Substation - 28S C22 1034L/1035L -from Bowmanton to W.Brook 3LG Bowmanton 240kV Substation -244S C23 1073L/1074L - Both circuits lost between Bowmanton and Elkwater 3LG Bowmanton 240kV Substation -244S C24 964L/983L - Line West towards Witla/Lethbridge (both lines) 3LG Elkwater 240kV Substation - 264S Table 2-13 List of Monitored Items for Dynamic Analysis Voltage & Frequency PSS/E Bus Number Relative Machine Angles P,Q Bus Name Bus # Name 477 Elk Water (POI) 240kV Cypress to Jenner 240kV 1482 Sheerness 1 531 Wild Rose 1 240 kV Empress to McNeill 138kV 4111 Sand Hill 462 Wild Rose 2 240 kV Bowmanton - Cypress 240kV 713 Medicine Hat #14 2531/3531 Wild Rose 1 34.5 kV Wild Rose 1 4631 Wild Rose 1 Terminals Wild Rose 2 430 West Brooks 138kV W. Brook to Bowmanton 1034L 680 Medicine Hat 138kV 240 kV line West to Lethbridge 1484 Anderson 240kV Anderson to Ware Junction 240 kV 167 North Lethbridge 240kV 159 Langdon 240kV 267 Dome Empress 138kV 1473 McNeill 138kV 677 Cypress 240kV 669 Bowmanton 240 kV 2.5.2 Generation Balancing For all the base cases, coal generation in Wabamun area 40 was adjusted to maintain the import/export levels from British Columbia and Saskatchewan at fixed levels as shown in Table 2-8 and Table 2-9. The same Wabamun area coal generation was adjusted to balance 400 MW of new Wild Rose wind generation. Alberta Electric System Operator 479,693 15 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 2.5.3 Wind Farm Model For ACCC analysis, the wind farm was modelled according to standards outlined in the AESO document entitled “Transmission Modelling Data Requirements – Wind Power Facility Supplement”. Each of the two 200 MW wind farms were modelled with 2 substation transformers, 10 equivalent feeder cables, 10 Generator step-up transformers, and 10 equivalent generators (shown in Figure 2-4). Additional details were added for the dynamic analysis. Since the nominal voltage is high at the Empress area buses, the 34.5 kV/240 kV transformers at Wild Rose collector substations were operated using a fixed tap of 1.05 pu for 2012 cases and 1.06 pu for 2013 cases. The tap settings were adjusted to keep the voltage level at the Cypress 240 kV bus at pre-Wild Rose voltage levels. The generator voltage controllers were set to hold the voltage at 1.0 pu at the 34.5kV side of the 34.5kV/240kV transformer. A 50 MVAR shunt reactor was installed at Bowmanton substation to mitigate the overvoltage violations during line energization and loss of all the generation at Wild Rose wind power plant for 2012 cases. The reactor was modeled out of service for most N-1 contingency cases, and may be of use in reducing existing Medicine Hat and Empress area over-voltages under contingency conditions if it is in service. Both wind farm collector models are lumped models and are modeled according to the connection diagrams provided by NEC (Drawing Nos. H-331725-A-E-82-0253 and H-331725-A-E-82-0254), dated August 12, 2008. Wind Farm Models assume 9% collector substation transformer impedances, base rated at 69 MVA. Overhead lines from collector substations to Elkwater were modeled with ACSR Curlew 1033.5 kcmil conductor with a single circuit. The overhead line from Bowmanton to Cypress (75km) is modeled with a single circuit ACSR Falcon 1590 kcmil conductor. All “Existing System” cases were analyzed with no Wild Rose transmission facilities in service. 2.5.4 LVRT and Reactive Power Criteria The proposed Wind Power Facility (WPF) meets AESO LVRT requirements, and meets requirements for dynamic and continuous VAR capability of the plant, as laid out in AESO document entitled “Wind_Power_Facility_Technical_Requirements_Revision0_signatures_JRF.pdf”. Alberta Electric System Operator 479,693 16 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Figure 2-4 PSS/E power flow model for 400 MW Wind Power Facility 2.5.5 SATR Transmission Assumptions The South Area Transmission Reinforcement (SATR) facilities modeled in the 2013 base cases include: - Double circuit 240 kV line between Bowmanton and West Brooks (1034L/1035L) - Double circuit 240 kV line between Elkwater and Whitla Substation - Expansion of Bowmanton Substation - Reinforcement and expansion in Cypress/Empress area Note: During the course of this study, the AESO determined that the ability to expand West Brooks to accept the line from Bowmanton was not practical. A new substation, Cassils, was developed to the west of West Brooks for terminating the Bowmanton line. This revised configuration is shown in Figure 1-1. From an electrical modeling standpoint, this topology modification has no material impact on the results presented in this study. (Figure 1-1 includes new facilities Southwest of Whitla which were not in the analysis). 2.5.6 Additional Transmission Assumptions For all the 2013 base cases a double circuit line was added between Janet and Peigan to represent 911L. Parameters of each line were set equal to the model available in the 2012 base cases. Rate A of each line was set to 1000 MVA. These modifications reflect the proposed upgrade of the Janet to Peigan Line in the SATR. 2.5.7 Additional Stability Analysis Assumptions, Observations, and Recommendations Dynamic analysis was performed using PSS/E version 30.3.3. The following assumptions were made in order to allow the cases to run: - For dynamic analysis, the wind farm was modelled according to standards outlined in the AESO document entitled “Transmission Modelling Data Requirements – Wind Power Facility Supplement”. Each of the two 200 MW wind farms were modelled with 2 substation Alberta Electric System Operator 479,693 17 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ - transformers, 2 equivalent feeder cables, 2 Generator step-up transformers, and 2 equivalent generators (shown in Figure 2-5). The 240kV/138kV transformers are operated at the same fixed tap settings as in the power flow cases. The generator voltage controllers were set to hold the voltage of the Elkwater 240kV bus. Category B and C three phase to ground fault contingencies were cleared in 6 cycles. Category C SLG fault and common breaker-fail events were cleared in 18 cycles. Several small generator units in the North with no validated models were netted with load to run the dynamic simulations, per AESO instructions. SVC models in service in loadflow but with disabled dynamic models were enabled in dynamics, per AESO instructions. The Whitla SVC dynamic model was copied from the similarly sized Langdon SVC as no dynamic model was available in DYR file. The Wind Turbine Generator Model version used in this study supplied directly by PTI in July, 2010 named AW1530X.obj. Documentation for the model was dated October 2009. The AVR model used was supplied in July 2010 by PTI named AWTVRW.OBJ. Figure 2-5 PSS/E dynamic model for 400 MW Wind Power Facility Alberta Electric System Operator 479,693 18 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 2.5.8 Special Wind Farm Considerations for Short Circuit Analysis Three‐phase and single-phase to ground short circuit studies were performed using PSS/E Version 30.3.3. The fault locations considered for the short circuit study are shown in Table 2-14. Table 2-14 Fault locations for Short Circuit Analysis Fault Location PSS/E Bus Substation Ware Junction 240kV 225 132S Jenner 240kV 260 275S Amoco Empress 240kV 262 163S West Brooks 138kV 276 121S Elkwater 240kV 477 264S West Brooks 240kV 430 28S Bowmanton 240kV 669 244S Cypress 1 138kV 674 562S Cypress 2 240kV 677 562S Medicine Hat 138kV 680 41S Sheerness 240kV 1481 807S Anderson 240kV 1484 801S Alberta Electric System Operator 479,693 19 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3.0 Existing System Assessment - 2012 Cases 3.1 Powerflow Analysis 3.1.1 Existing System Powerflow Analysis Summary For existing system powerflow simulations, several overloading conditions are evident: - Elerslie to Argyle 240 kV Circuit: This overload is primarily due to high VAR flows stemming from the power factor on lines in the Wabamun generation area. VAR management in this region may be adequate to mitigate this problem or it may be alleviated by proposed system expansions in the area. This region is far away from the Wild Rose project area, and this overload is not impacted by the addition of the new wind generation. Empress to Cypress 138 kV Circuit: This line is rated at 90 MVA and is overloaded under several load scenarios and contingencies. The overload is made worse by the addition of the Wild Rose project. The thermal capacity of this line will be upgraded to mitigate these overloads as part of the scope of the Wild Rose 1 project. Nevis 240/138 kV Transformer: This transformer overloads under certain load conditions when the 240 kV line between Nevis and Cordel is out of service. The overload is made worse by the addition of the Wild Rose project. It is expected that this overload will be handled by future mitigative solutions currently under assessment by the AESO. - - Note: The generation dispatch assumptions summarized in Section 2.3 for the 2012 cases are critical in ensuring the N-0 (System Intact) scenarios, with the 2012 system assumptions, are free of overloads. Altering these dispatch assumptions can cause system intact loading violations, exacerbate contingency overloading violations, and cause new overloading violations. Until such time as transmission reinforcements are in place, it is understood that the AESO will develop operational rules to manage the potential system constraints. 3.1.2 Special Mitigation Notes and Assumptions for 2012 Cases 1. 2. 3. The Janet to Peigan (911L) line is overloaded in N-0 conditions and overloading becomes worse during N-1 contingencies. Under N-0 conditions 911L is overloaded, and with 200 MW Wild Rose wind generation added, overloading increases by a further 9%. With approximately 400 MW Wild Rose wind generation, overloading increases by further 17% (average values). Since this violation occurs in every case and is known to the AESO, it is excluded from the results tables. Non-convergent contingency: Langdon 240kV/500kV Transformer outage in 2012 Summer Light cases. This problem is appears in all the 2012 Summer light base cases irrespective of the Wild Rose Wind power project. A 50 MVAR shunt reactor will be installed at Bowmanton substation to mitigate the overvoltage violations in Wild Rose area due to sudden loss(trip) of 400 MW Wild Rose wind Alberta Electric System Operator 479,693 20 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 4. 5. 6. 7. generation or line energization. (More detailed analysis is presented in 5.1.7 Reactor Design Section.) Blackie area 138kV over-voltages may be mitigated by adjusting local transformer tap settings. Sheerness area 240kV over-voltages may be mitigated by adjusting local transformer tap settings. Nevis 240kV/138kV transformer overloading may be mitigated by backing down wind generation at IP-518 and IP-634. Capacitor bank operating voltage levels at Calgary area were adjusted to 1.05pu-1.10pu from 0.95pu-1.10pu for 240kV buses and to 1.03pu-1.05pu from 1.00pu-1.05pu for 138kV buses to mitigate the overvoltage and overloading conditions of the Langdon SVC transformer. However, overvoltage and overloading conditions are still present for some N-1 contingencies. 3.1.3 2012 Summer Light Cases – Existing System 3.1.3.1 Contingency description 2012 Summer Light cases Table 3-4 shows a reduced list of contingencies which may be used for reference in the subsequent tables. Although all Category B contingencies in the regions identified in Table 2-11 were tested, these contingencies were of particular interest as they exhibited some manner of criteria violation. Table 3-1 2012SL Contingency description Note 1 Contingency Note 1 Outage element D1 Ware Junction to West Brook 4 240kV (931L) D2 Fincastle 7 to Taber CKT 10 138kV(610L) D3 Bulls Head 7 to Medicine Hat 7 CKT 80 138kV D4 Red Deer to Nevis 240kV (912L) D5 Langdon 4 to West Brook 240kV (924L) D7 Nevis 4 to Cordell 4 240kV (9L20) D8 Battle River 79 to Cordell 4 CKT 79 240kV D9 Anderson 4 240kV/138 1T Transformer D10 Willesd 4 to W.Grn Tap CKT 95 240kV D11 Red Deer to Benalto CKT 00 240kV (900L) D12 Gleiche 7 to Namakwa 7 CKT 33 138kV D13 Tilley 7 to West Brook 7 CKT 66 138kV D14 Wint H17 to Bull Pond 7 CKT 85 138kV D16 Gleiche 7 to Queens Town CKT 76 138kV D17 Janet 4 to East Calgary CKT 17 240kV D18 Dome EM 4 to Cypress 2 CKT 11 240kV (945L) D19 Dome EM 7 to Cypress 1 CKT 69 138kV Comprehensive analysis was performed, but this table reflects problematic contingencies only. Alberta Electric System Operator 479,693 21 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3.1.3.2 S1C2ES - ( 2012 Summer Light case, 0 MW Wild Rose, 0 MW Import from Sask.) Table 3-2 S1C2ES overloaded branches and voltage violations Figure Contingency Overloaded element % Overload Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltages ( 1.095pu) S1ES_N0 N-0 None - S1ES_D7 D7 Nevis 240kV /138kV transformer 115% D8,D9, D14 None - D12 None - Many (N-1) None - 100MVA None Sheerness area (240kV) overvoltages (1.105pu) Blackie (138kV) over-voltages (1.105pu) Empress (240kV) over-voltages 1 (1.109pu) Additional Notes: 1. Empress area overvoltage may be mitigated by adjusting transformer tap settings and switching off capacitor banks at Dome Empress 138kV bus. 3.1.3.3 S2C2ES - ( 2012 Summer Light case, 0 MW Wild Rose, 150 MW Import from Sask.) Table 3-3 S2C2ES overloaded branches and voltage violations Figure Contingency Overloaded element S2ES_N0 N-0 S2ES_D7 D7 S2ES_D18 S2ES_D19 D18, D19 D1,D8, D9,D14 % Overload None Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltage (1.097pu) - Nevis 240kV /138kV transformer Empress A7 to Cypress 1 138kV 128% 100MVA None 110%, 129.1% 90MVA None None - Many (N-1) None - Many (N-1) None - D1 None - Many (N-1) None - Sheerness area (240kV) overvoltages (1.11pu) Backbone area (240kV) overvoltage (1.109pu) Blackie area (138kV) overvoltages (1.107pu) Brooks area (240kV) overvoltages (1.102pu) Empress area (240kV) 1 overvoltages (1.114pu) Additional Notes: 1. Empress area overvoltage may be mitigated by adjusting transformer tap settings and switching off capacitor banks at Dome Empress 138kV bus. Alberta Electric System Operator 479,693 22 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3.1.3.4 S3C2ES - ( 2012 Summer Light case, 0 MW Wild Rose, 150 MW export to Sask.) Table 3-4 S3C2ES overloaded branches and voltage violations Figure Contingency Overloaded element % Overload S3ES_N0 N-0 None - S3ES_D7 D7 Nevis 240kV /138kV transformer 105% D8,D14 None - Many (N-1) None - Many (N-1) None - Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltage (1.099pu) 100MVA None Sheerness area (240kV) overvoltages (1.106pu) Backbone area (240kV) overvoltage (1.108pu) Blackie area (138kV) overvoltage (1.108pu) 3.1.4 2012 Summer Peak Cases – Existing System 3.1.4.1 Contingency description 2012 Summer peak cases Table 3-5 shows a reduced list of contingencies which may be used for reference in the subsequent tables. Although all contingencies in the regions identified in Table 2-11 were monitored, these contingencies were of particular interest as they exhibited some manner of criteria violation. Alberta Electric System Operator 479,693 23 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 3-5 2012SP contingency description Note 2 Contingency Note 2 Outage element E1 Red Deer to Nevis 240kV (912L) E2 Langdon 4 to West Brook 240kV (924L) E4 Nevis 4 to Cordell 4 240kV (9L20) E5 Ware Junction to West Brook 4 240kV (931L) E6 Tilley 7 to West Brook 7 CKT 66 138kV E7 Bellamy 4 to Argyll W CKT 04 240kV E8 Langdon 4 240kV/500kV T1 Transformer E9 Ellersli to Genesee 4 CKT 09 500kV (1209L) E10 Battle River 79 to Cordell 4 CKT 79 240kV E11 Anderson 4 240kV/138 1T Transformer E12 Wint H17 to Bull Pond 7 CKT 85 138kV E13 Gaetz 4 to Red Deer 4 CKT 14 240kV E14 Dome EM 4 to Cypress 2 CKT 11 240kV (945L) E15 Dome EM 7 to Cypress 1 CKT 69 138kV E16 Chappice Lake 7 to Medicine Hat 7 CKT 60 138kV E17 Chappice Lake to Glenridge CKT 58 138kV E18 Cypress 1 to Glenridge CKT58 138kV Comprehensive analysis was performed, but this table reflects problematic contingencies only. Alberta Electric System Operator 479,693 24 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3.1.4.2 S4C2ES - ( 2012 Summer peak case, 0 MW Wild Rose, 0 MW export to Sask.) Table 3-6 S4C2ES overloaded branches and voltage violations Figure Contingency Overloaded element % Overload S4ES_N0 N-0 None - S4ES_E7 E7 Ellersli to Argylle 240kV 100% E8,E9, E13 None - E9,E13 None - E11 None - Many (N-1) None - Rating A 419MVA Other system performance concerns (Maximum reported) Blackie area (138kV) Overvoltage (1.094pu) None Backbone area (500 kV,240kV) over-voltages (1.135pu,1.166pu), high voltage deviation Backbone area (500 kV,240kV) low voltage (0.962pu,0.946pu) Sheerness area (240kV) over-voltages (1.103pu) Blackie area (138kV) over-voltages (1.102pu) Alberta Electric System Operator 479,693 25 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3.1.4.3 S5C2ES - ( 2012 Summer peak, 0 MW Wild Rose, 150 MW import from Sask.) Table 3-7 S5C2ES overloaded branches and voltage violations Figure Contingency Overloaded element % Overload S5ES_N0 N-0 None - S5ES_E7 E7 S5ES_E15 E15 Ellersli to Argylle 240kV Empress A7 to Cypress 1138kV Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltage (1.094pu) 101% 419MVA None 108% 90MVA None E8,E9, E13 None - E9,E13 None - E10,E11 None - Many (N-1) None - E5 None - Backbone area (500 kV,240kV) over-voltages (1.135pu,1.167pu), high voltage deviation Backbone area (500 kV,240kV) low voltage (0.964pu,0.949pu) Sheerness area (240kV) over-voltages (1.103pu) Blackie area (138kV) over-voltages (1.103pu) Empress area (240kV) 1 overvoltage (1.10pu) Additional Notes: 1. Empress area overvoltage may be mitigated by adjusting transformer tap settings. 3.1.4.4 S6C2ES - ( 2012 Summer peak case, 0 MW Wild Rose, 150 MW export to Sask.) Table 3-8 S6C2ES overloaded branches and voltage violations Overloaded % Figure Contingency Rating A element Overload S6ES_N0 N-0 None - E8, E9, E13 None - E9,E13 None - E11 None - Many (N-1) None - Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltage (1.098pu) Backbone area (500 kV,240kV) over-voltages (1.133pu,1.165pu), high voltage deviation Backbone area (500 kV,240kV) low voltage (0.953pu,0.945pu) Sheerness area (240kV) over-voltages (1.103pu) Blackie area (138kV)over-voltages (1.105pu) Alberta Electric System Operator 479,693 26 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3.2 Stability Analysis 3.2.1 Existing System Dynamic Analysis Summary Dynamic analysis was performed using PSS/E version 30.3.3. For each of the base cases analyzed, a set of 36 contingencies was applied, including selected Category B and C disturbances. The primary goal of these studies is to determine whether the system remains dynamically stable under fault and outage conditions, but each run was examined for additional concerns, such as post-fault voltage, AVR operation, machine tripping, poorly damped oscillations, and any other problematic behaviour. The assumptions and additional observations discussed in section 2.5.7 apply for existing system analysis as well as “wind added” analysis. The 2012 cases studied here do not exhibit dynamic instability due to the loss of the lines south from Anderson. The cases use the same dispatch assumptions as the steady state analysis, that being existing units operating under reduced power to prevent overloading on the Red-Deer Nevis circuit. North-South power flow through Anderson is reduced, and the loss of this circuit no longer causes instability under these conditions. This issue is not significantly impacted by the addition of the Wild Rose plant. Specific dynamic concerns identified with the existing system are: 1. Castle, MacBride, Kettles, and Summerview wind farms experience tripping in some contingencies. This is due to undervoltage protection operation. This tripping may not be realistic, and are represented using older unsupported PSS/E models. The existing system wind farm tripping is not impacted significantly by the addition of the Wild Rose plant. 2. Loss of the double circuit line (N-2) between Cypress and Ware Junction leaves the Empress area in a very weak condition, and depending on the status of the McNeil DC tie can result in load/generation imbalance in the area. This imbalance may be sufficient to cause instability. This condition is not eliminated by the addition of Wild Rose wind farm in 2012, but the generation/load balance does change depending on wind levels. In 2013, it is expected that this problem will be reduced due to the strengthened ties into the Empress area as planned in the Hanna area upgrades. 3. It is noted that while the system is capable of sustaining SLG faults with long clearing times (during fault-and-common-breaker-fail events), many breaker fail events cause instability if the fault type is LLLG instead of SLG. Alberta Electric System Operator 479,693 27 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3.2.2 Contingency Description Existing System Cases Table 3-9 shows a list of contingencies and events which were applied for all dynamic analysis cases. Table 3-9 List of Outages and Events Applied for Dynamic Analysis Contingency Reference # Elements Outage Fault Fault Location (line end) CAT B (N-1) C1 1009L - from Bowmanton to Cypress 3LG Bowmanton Substation - 244S C2 945L or 951L - from Cypress to Jenner 3LG Cypress 240kV Substation - 562S C3 944L - from Jenner to Ware Junction 3LG Ware Jct 240kV Substation -132S C4 931L - from Ware Junction to W.Brook 3LG Ware Jct 240kV Substation -132S C5 9L 933 - from Anderson to W.Brook 3LG Anderson 240kV Substation -801S C6 9L 933 - from Anderson to W.Brook 3LG West Brooks 240kV Substation - 28S C7 9L950 or 9L934 - from Ware Junction to Anderson 3LG Ware Junction 240kV Substation - 132S C8 9L950 or 9L934 - from Ware Junction to Anderson 3LG Anderson 240kV Substation - 801S C9 923L or 924L - from W. Brook to N.Lethbridge ( Milo for 2013 cases) 3LG West Brooks 240kV Substation - 28S C10 Amoco Empress 163S (240/138kV transformer) 3LG Amoco Empress 240kV Substation -163S C11 830L - from Cypress 562S to McNeill 840S 3LG Cypress 138kV Substation -562S C12 Elkwater to Wild Rose 1 (Loss of 200MW) 978L 3LG Elkwater 240kV Substation - 264S C13 Elkwater to Eagle Butte (Loss of 200 MW) 1076L 3LG Elkwater 240kV Substation - 264S C14 One circuits lost between Bowmanton and Elkwater - 1073L/1074L 3LG Bowmanton 240kV Substation -244S C15 Sudden loss of all 400 MW wind 978L and 1076L N/A N/A C16 1034L or 1035L - from Bowmanton to W.Brook (2013 only) 3LG Bowmanton 240kV Substation -244S C16B Rd Deer to Nevis - 912L 3LG Red Deer240kV Substation - 63S CAT C (N-2) C17 945L/951L - from Cypress to Jenner 3LG Cypress 240kV Substation - 562S C18 944L - from Jenner to Ware Junction 3LG Ware Jct 240kV Substation -132S C19 9L950/9L934 - from Ware Junction to Anderson 3LG Anderson 240kV Substation -801S C20 9L950/9L934 - from Ware Junction to Anderson 3LG Ware Junction 240kV Substation - 132S C21 923L/924L - from W. Brook to N.Lethbridge (Milo for 2013 cases) 3LG West Brooks 240kV Substation - 28S C22 1034L/1035L -from Bowmanton to W.Brook 3LG Bowmanton 240kV Substation -244S C23 1073L/1074L - Both circuits lost between Bowmanton and Elkwater 3LG Bowmanton 240kV Substation -244S C24 964L/983L - Line West towards Witla/Lethbridge (both lines) 3LG Elkwater 240kV Substation - 264S Breaker Failure Contingencies ( Delayed clearing time 18cycles) C25 Janet to Red Deer std time and Janet to Langdon delayed 1LG Janet 240kV Substation - 74S C26 Janet to Red Deer std time and trip Janet to Peigan delayed 1LG Janet 240kV Substation - 74S C27 Langdon to Milo std time and Langdon to Janet delayed 1LG Langdon 240kV Substation - 102S C28 1LG Langdon 240kV Substation - 102S C29 Langdon to Janet std time and Langdon SVC delayed time West Brooks to Milo Junction std time and West Brooks to Ware Junction delayed time 1LG West Brooks 240kV Substation - 28S C30 Red Deer to Gaetz std time and Red Deer to Nevis delayed time 1LG Red Deer 240kV Substation - 63S C31 Nevis to Cordel std time and Nevis to Red Deer delayed time 1LG Nevis 240kV Substation - 766S C32 Cordel to Nevis std time and BR Unit 5 delayed time 1LG Cordel 240kV Substation C33 1LG Anderson 240kV Substation - 801S C35 Anderson to West Brooks std time and SH Unit 1 delayed time Ware Junction to Jenner std time and Ware Junction to West Brooks delayed time Jenner to Amoco Empress std time and Jenner to Ware Junction delayed time C36 Langdon to Milo std time and Nevis to Red Deer delayed time C34 1LG 1LG Ware Junction 240kV Substation - 132S Jenner 240kV Substation - 275S N-1-1 contingencies ( 2nd fault and outage after 1st outage reaches steady state) 3LG Red Deer 240kV Substation - 63S Alberta Electric System Operator 479,693 28 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3.2.3 2012 Summer Light Cases – Existing System Table 3-10 2012 Summer Light Case with no Saskatchewan Import and 0 MW Wild Rose wind S1C2ES: Existing System - 2012 Light Load (Pre-SATR) with no McNeil activity Contingency Expected Stable? (Summary) C1 C2 C3 C4 C5 C6 C7 C8 N-1 C9 C10 C11 C12 C13 C14 C15 C16 C16B C17 C18 C19 C20 N-2 C21 C22 C23 C24 C25 C26 C27 C28 Breaker C29 fail (SLG - C30 18cycle) C31 C32 C33 C34 C35 N-1-1 C36 N/A √ √ √ √ √ √ √ √ √ √ N/A N/A N/A N/A N/A √ X X √ √ √ N/A N/A N/A √ √ √ √ √ √ √ √ √ √ √ √ Comments N/A No tripping 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,11 - KETTLES Tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,11- KETTLES Tripped (VTGTPTA - UV) No tripping No tripping N/A N/A N/A N/A N/A 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) Unstable (loss of 240 ccts from Cypress to Jenner… no supply to Empress Area load) Unstable (same comment as C17) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,11- KETTLES Tripped (VTGTPTA - UV) N/A N/A N/A No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) Alberta Electric System Operator 479,693 29 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3.2.4 2012 Summer Peak Cases – Existing System Table 3-11 2012 Summer Peak Case with 150 MW Saskatchewan Import and 0 MW Wild Rose wind S5C2ES: Expected Contingency Stable? (Summary) C1 N/A C2 √ C3 √ C4 √ C5 √ C6 √ C7 √ C8 √ N-1 C9 √ C10 √ C11 √ C12 N/A C13 N/A C14 N/A C15 N/A C16 N/A C16B √ C17 √ C18 √ C19 √ C20 √ N-2 C21 √ C22 N/A C23 N/A C24 N/A C25 √ C26 √ C27 √ C28 √ Breaker C29 √ fail (SLG - C30 √ 18cycle) C31 √ C32 √ C33 √ C34 √ C35 √ N-1-1 C36 √ Existing System - 2012 Heavy Load (Pre-SATR) with 150 MW McNeil import Comments N/A No tripping 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8 - KETTLES Tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8 - KETTLES Tripped (VTGTPTA - UV) No tripping No tripping N/A N/A N/A N/A N/A 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) No tripping (loss of 240 ccts from Cypress to Jenner, Empress area load supplied by McNeil) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8 - KETTLES Tripped (VTGTPTA - UV) N/A N/A N/A No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) Alberta Electric System Operator 479,693 30 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3.3 Short Circuit Analysis - Existing System A short circuit study was performed using the Summer Peak case with 150MW import from Saskatchewan (Case designation S5C2ES) to simulate the worst case short circuit faults in existing system. The results for the existing system analysis are shown in Table 3-12. Table 3-12 2012 Summer Peak Case with 150MW Saskatchewan Import and 0MW Wild Rose wind 2012 Summer Peak Case with 150MW Saskatchewan Import and 100MW BC Export (Existing System, S5C2ES) Pre Positive Seq Zthev Zero Seq Zthev Base 3LG SLG Fault (pu) (pu) Fault Location Voltage Fault Fault Voltage (kV) (kA) (kA) R jX R jX (pu) 1.0742 10.402 0.00394 0.02453 7.910 0.00976 0.04617 Ware Junction 240 Jenner 240 1.0748 6.798 0.00580 0.03759 4.136 0.02617 0.10825 Amoco Empress 240 1.0710 5.691 0.00535 0.04496 3.167 0.03822 0.15016 West Brooks 138 1.0327 13.099 0.00719 0.03219 13.627 0.00217 0.02879 Elkwater 240 N/A N/A N/A N/A N/A N/A N/A West Brooks 240 1.0550 10.772 0.00480 0.02306 11.281 0.00202 0.01969 Bowmanton 240 N/A N/A N/A N/A N/A N/A N/A Cypress 1 138 1.0225 8.459 0.00519 0.05030 5.315 0.03566 0.13873 Cypress 2 240 1.0714 5.653 0.00547 0.04526 3.178 0.03794 0.14883 Medicine Hat 138 0.9965 5.381 0.02313 0.07394 5.413 0.00797 0.07720 Sheerness 240 1.0865 12.491 0.00238 0.02079 12.458 0.00186 0.01857 Anderson 240 1.0859 12.815 0.00235 0.02025 12.910 0.00171 0.01750 Alberta Electric System Operator 479,693 31 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 4.0 Proposed Connection Scenarios Two connecting alternatives have been studied for the Wild Rose wind farm connection, referred to here as concept numbers 1 and 2. These two alternatives represent various concepts under consideration by NEC, and are illustrated in Figure 4-6 and Figure 4-7 (Concept 1) and Figure 4-8 and Figure 4-9 (Concept 2). Subsequent to the commencement of this analysis, concept 2 was selected, and all concept 1 analysis was abandoned. Both approaches utilize 240kV switching stations to connect to the AESO system. The switching stations would be a breaker and a half arrangement. The difference between the two alternatives would be that the wind farms in Concept 1 would be connected in to only one 240kV line for either wind farm by means of two separate switching stations where in Concept 2 both farms would be connected in to both 240kV lines using a common switching station. Either approach was considered acceptable for consideration by the AESO. Subsequent to the commencement of this analysis, concept 2 was selected by NEC as the preferred alternative. This selection was based primarily on considerations associated with the preferred route selected by AltaLink for the SATR project. The AESO accepted either connection for consideration and was indifferent if NEC determined to remove one connection alternative from consideration. Alberta Electric System Operator 479,693 32 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 4.1 Alternative 1 ‐ Concept # 1 Wild Rose wind farm connection Amoco Empress 163S 138 kV existing in base case 1002L 240 kV existing in base case 240 kV Wind Facilities 1011L 945L Jenner 275S To Ware 944L/951L Junction 132S Cypress 562S 669L 830L McNeil 840S 760L 75 km Single Circuit 100L East Medicine Hat 244S (B0) Chappice Lake 649S 75.6 km Medicine Hat 41S 54.2km Double Circuit Elkwater 264S Single Circuit 172L 15 km WR1 0.1‐1.0 km WR2 2012 (pre‐SATR): Concept 1 Figure 4‐6 2012 Pre ‐ SATR Wild Rose connection concept #1 (Not Studied) Alberta Electric System Operator 479,693 33 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Amoco Empress 163S 138 kV existing in base case 1002L 240 kV existing in base case 240 kV Wind Facilities 1011L 945L Jenner 275S To Ware 944L/951L Junction 132S Cypress 562S 669L 830L McNeil 840S 1034L 760L 75 km 1035L Single Circuit 100L East Medicine Hat 244S (B0) Chappice Lake 649S 75.6 km Medicine Hat 41S 54.2km Double Circuit Whitla 251S Elkwater 264S Single Circuit 172L 15 km WR1 0.1‐1.0 km WR2 2013 (SATR): Concept 1 Figure 4‐7 2013 SATR Wild Rose connection concept #1 (Not Studied) Alberta Electric System Operator 479,693 34 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 4.2 Alternative 2 ‐ Concept # 2 Wild Rose Wind Farm connection 138 kV existing in base case Amoco Empress 163S 1002L 240 kV existing in base case 240 kV Wind Facilities 1011L 945L Jenner 275S To Ware 944L/951L Junction 132S Cypress 562S 669L 830L McNeil 840S 760L 75 km Single Circuit 100L East Medicine Hat 244S (B0) Chappice Lake 649S 47.2 km Medicine Hat 41S Double Circuit Elkwater 264S 0.1 ‐ 1.0 km Single Circuit 172L 36.4km WR2 WR1 2012 (pre‐SATR): Concept 2 Figure 4‐8 2012 Pre ‐ SATR Wild Rose connection concept #2 Alberta Electric System Operator 479,693 35 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Amoco Empress 163S 138 kV existing in base case 1002L 240 kV existing in base case 240 kV Wind Facilities 1011L 945L Jenner 275S To Ware 944L/951L Junction 132S Cypress 562S 669L 830L McNeil 840S 1034L 760L 75 km 1035L Single Circuit 100L East Medicine Hat 244S (B0) Chappice Lake 649S 47.2 km Medicine Hat 41S Double Circuit Whitla 251S Elkwater 264S 0.1 ‐ 1.0 km Double Circuit Single Circuit 172L 36.4km WR2 WR1 2013 (SATR): Concept 2 Figure 4‐9 2013 SATR Wild Rose connection concept #2 Alberta Electric System Operator 479,693 36 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.0 Evaluation of Proposed Connection 5.1 Powerflow Analysis 5.1.1 Powerflow Analysis Summary (2012 Pre-SATR) Of the 2012 cases studied, the worst overloading occurs with the 2012 summer light case with 150 MW importing from Saskatchewan (S2C2GGA). For powerflow simulations with the Wild Rose Wind Farm added, several overloading conditions are evident: - - - - - - Elerslie to Argyle 240 kV Circuit: This overload is primarily due to high VAR flows stemming from poor power factor on lines in the Wabamun generation area. VAR management in this region may be adequate to mitigate this problem. This region is far away from the Wild Rose project area, and this overload is not substantially impacted by the addition of the new wind generation. Empress to Cypress 138 kV Circuit: This line is rated at 90 MVA and is overloaded under several load scenarios and contingencies. The overload is made worse by the addition of the Wild Rose project. The thermal capacity of this line must be upgraded to mitigate these overloads. Nevis 240/138 kV Transformer: This transformer overloads under certain load conditions when the 240 kV line between Nevis and Cordel is out of service. The overload is made worse by the addition of the Wild Rose project. It is expected that this overload will be mitigated by future cutplane management currently being evaluated by the AESO. West Brooks – Bassano Tap – Queenstown 138 kV Circuit: The addition of the Wild Rose Wind Farm overloads this circuit under contingency conditions. A RAS scheme exists to manage this overload, and should be extended to account for the Wild Rose project. Medicine Hat – Suffield 138 kV Circuit, and Medicine Hat – Chappice Lake – Glenridge – Cypress Circuit: The 138 kV network around Medicine Hat is stressed by the addition of any injection of power in the Cypress/Empress area, including Wild Rose and the McNeil DC tie. Wind connecting into the 138 kV system around Medicine Hat also stresses this network, causing overloads under contingency conditions. It is expected that the SATR network upgrades will mitigate these overloads. Red Deer – Nevis 138 kV Circuit (912L): The dispatch levels for existing area generators in the 2012 “system intact” cases were set at low levels to ease the overloading of the Red Deer to Nevis (912L) transmission line and allow the impact of full output of the Wild Rose Power Projects to be studied. However, under contingency conditions, this circuit will overload unless generation is further reduced. Several additional marginal overloads are evident under contingency conditions, including Ware Junction to West Brook 240kV, Blackie 7 to Vulcan 7 138kV and Empress A7 to Dome Empress 7 138kV. These overloads indicate that the system is operating in a marginal state during these contingencies, and should be carefully examined in future study efforts. Note: The generation dispatch assumptions summarized in section 2.3 for the 2012 cases are critical in ensuring the N-0 (System Intact) scenarios, considering the 2012 system assumptions, are free of overloads. Altering these dispatch assumptions can cause system intact loading violations, exacerbate Alberta Electric System Operator 479,693 37 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ contingency overloading violations, and cause new overloading violations. In particular, south system wind interest and the existing generation levels are critical assumptions for all Pre-SATR 2012 cases. 5.1.2 2012 Summer Light Cases 5.1.2.1 Contingency Description 2012 Summer Light Cases Table 5-1 shows a reduced list of contingencies which may be used for reference in the subsequent tables. Although all contingencies in the regions identified in Table 2-11 were monitored, these contingencies were of particular interest as they exhibited some manner of criteria violation. Table 5-1 2012SL Contingency description Note 3 Contingency Note 3 Outage element D1 Ware Junction to West Brook 4 240kV (931L) D2 Fincastle 7 to Taber CKT 10 138kV(610L) D3 Bulls Head 7 to Medicine Hat 7 CKT 80 138kV D4 Red Deer to Nevis 240kV (912L) D5 Langdon 4 to West Brook 240kV (924L) D7 Nevis 4 to Cordell 4 240kV (9L20) D8 Battle River 79 to Cordell 4 CKT 79 240kV D9 Anderson 4 240kV/138 1T Transformer D10 Willesd 4 to W.Grn Tap CKT 95 240kV D11 Red Deer to Benalto CKT 00 240kV (900L) D12 Gleiche 7 to Namakwa 7 CKT 33 138kV D13 Tilley 7 to West Brook 7 CKT 66 138kV D14 Wint H17 to Bull Pond 7 CKT 85 138kV D16 Gleiche 7 to Queens Town CKT 76 138kV D17 Janet 4 to East Calgary CKT 17 240kV D18 Dome EM 4 to Cypress 2 CKT 11 240kV (945L) D19 Dome EM 7 to Cypress 1 CKT 69 138kV Comprehensive analysis was performed, but this table reflects problematic contingencies only. Alberta Electric System Operator 479,693 38 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.2.2 S1C2GA - (2012 Summer Light case, 200 MW Wild Rose, 0 MW export to Sask.) Table 5-2 S1C2GA overloaded branches and voltage violations Figure Contingency S1GA_N0 N-0 S1GA_D7 D7 S1GA_D18 D18 Overloaded element None Nevis 240kV /138kV transformer Empress A7 to Cypress 1 138kV D1,D8, D9,D14 None D11 None D1,D8 None D16 (Many N-1) None Existing system 1.095pu % Overload Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) over-voltages (1.096pu) - 115% 130% 100MVA None None 100%1 90MVA None 1.105pu None 1.109pu 1.105pu None - None - None - None - Sheerness area (240kV) over-voltages (1.106pu) Backbone area (240kV) over-voltages (1.102pu) Empress area (240kV) over-voltages (1.108pu) Blackie area (138kV) over-voltages (1.10pu) 1 Although this overload is new for this contingency, the overloaded element is overloaded in other existing system cases (eg. S2C2ES) Alberta Electric System Operator 479,693 39 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.2.3 S2C2GA - ( 2012 Summer Light case, 200 MW Wild Rose, 150 MW import from Sask.) Table 5-3 S2C2GA overloaded branches and voltage violations Existing Figure Contingency Overloaded element S2GA_N0 N-0 None N-0 None S2GA_D4 S2GA_D5 S2GA_D7 D4, D5, D7 West Brook 7 to Bassano Tap 138kV S2GA_D7 D7 S2GA_D4 D4 S2GA_D1 8 System 1.097pu Nevis 240kV /138kV transformer Queens Town to Bassano Tap 138kV % Overload Rating A - Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltages (1.097pu) Empress area (240kV) overvoltages (1.101pu) None - None None None 128% 111.7% 103.0% 101.6% 121MVA None 142% 100MVA None 103% 121MVA None None Many (N-1) Empress A7 to Cypress 1 138kV 129.1% up to 145% D1,D8, D9,D14, None 1.110pu None D11 None 1.109pu None D1 None 1.114pu None D16 None 1.107pu None 90MVA Reported separately in this table Sheerness area (240kV) overvoltages (1.105pu) Backbone area (240kV) overvoltages (1.105pu) Empress area (240kV) overvoltages (1.107pu) Blackie area (138kV) overvoltages (1.110pu) Alberta Electric System Operator 479,693 40 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.2.4 S3C2GA - (2012 Summer Light case, 200 MW Wild Rose, 150 MW export to Sask.) Table 5-4 S3C2GA overloaded branches and voltage violations Figure S3GA_N0 S3GA_D7 Contingency Overloaded element Existing System % Overload N-0 None 1.099pu - D7 Nevis 240kV /138kV transformer 105% 119% D1,D8, D9,D14 None D11 None D1 None 1.106% 1.108pu None None None None 1.108pu D16 None None Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) over-voltages (1.097pu) 100MVA None Sheerness area (240kV) overvoltages (1.105pu) Backbone area (240kV) overvoltages (1.103pu) Empress area (240kV) overvoltages (1.101pu) Blackie area (138kV) overvoltage (1.100pu) Alberta Electric System Operator 479,693 41 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.2.5 S1C2GGA - (2012 Summer Light case, 400 MW Wild Rose, 0 MW export to Sask.) Table 5-5 S1C2GGA overloaded branches and voltage violations Overloaded % Overload Figure Contingency element Existing System S1GGA_N0 N-0 None 1.095pu - S1GGA_D4 S1GGA_D5 S1GGA_D7 D4, D5, D7 None 115% 108% 105% 121MVA None S1GGA_D4 D4 None 106% 121MVA None S1GGA_D7 D7 115% 144% 100MVA None S1GGA_D18 D18 West Brook 7 to Bassano Tap 138kV Queens Town to Bassano Tap 138kV Nevis 240kV/ 138kV transformer Empress A7 to Cypress 1 138kV None 138% 90MVA None D8, D9 None 1.105pu - D11 None None - D12 None 1.105pu - Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltages (1.094pu) Sheerness area (240kV) overvoltages (1.104pu) Backbone area (240kV) overvoltages (1.101pu) Blackie area (138kV) overvoltages (1.106pu) Alberta Electric System Operator 479,693 42 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.2.6 S2C2GGA - (2012 Summer Light, 400 MW Wild Rose, 150 MW import from Sask.) Table 5-6 S2C2GGA overloaded branches and voltage violations Figure Contingency Overloaded element Existing System S2GGA_N0 N-0 None 1.097pu S2GGA_N0 N-0 S2GGA_D1 S2GGA_D5 S2GGA_D1 S2GGA_D2 S2GGA_D3 S2GGA_D4 S2GGA_D5 S2GGA_D7 D1, D5 D1, D2, D3 D4, D5, D7 S2GGA_D1 D1 S2GGA_D4 S2GGA_D5 S2GGA_D7 D4, D5, D7 S2GGA_D1 D1 S2GGA_D7 D7 S2GGA_D18 Many (N-1) Empress A7 to Cypress 1 138kV Red Deer to Nevis 240kV (912L) Suffield 7 to Medicine Hat 7 138kV (892L) West Brook 7 to Bassano Tap 138kV Chappice Lake to Glenridge 138kV Queens Town to Bassano Tap 138kV Cypress 1 to Glenridge 138kV Nevis 240kV /138kV transformer Empress A7 to Cypress 1 138kV % Overload Rating A - 90MVA None 488MVA None 67MVA None 121MVA None 104% 90MVA None 118% 111% 107% 121MVA None 104% 90MVA None 128% 155% 100MVA None 129.1% up to 184% 90MVA None None None None None None None None 105.6% Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltages (1.092pu) 109.0% 102.2% 121% 117% 103% 127% 120% 116% D8, D9 None 1.11pu - D10, D11 None 1.109pu - D12 None 1.107pu - Sheerness area (240kV) overvoltages (1.104pu) Backbone area (240kV) overvoltage (1.101pu) Blackie area (138kV) overvoltage (1.106pu) Alberta Electric System Operator 479,693 43 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.2.7 S3C2GGA - (2012 Summer Light case, 400 MW Wild Rose, 150 MW export to Sask.) Table 5-7 S3C2GGA overloaded branches and voltage violations % Overload Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltages (1.093pu) Figure Contingency Overloaded element Existing System S3GGA_N0 N-0 None 1.099pu - S3GGA_D7 D7 105% 133% 100MVA None S3GGA_D4 D4 None 103% 121MVA None Nevis 240kV /138kV transformer West Brook 7 to Bassano Tap 138kV D8, D9 None D11 (Many N-1) None 1.106pu 1.108pu - - Rating A Sheerness area (240kV) overvoltages (1.104pu) Backbone area (240kV) overvoltages (1.102pu) Alberta Electric System Operator 479,693 44 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.3 2012 Summer Peak Cases 5.1.3.1 Contingency Description 2012 Summer Peak Cases Table 5-8 shows a reduced list of contingencies which may be used for reference in the subsequent tables. Although all contingencies in the regions identified in Table 2-11 were monitored, these contingencies were of particular interest as they exhibited some manner of criteria violation. Table 5-8 2012SP contingency description Note 4 Contingency Note 4 Outage element E1 Red Deer to Nevis 240kV (912L) E2 Langdon 4 to West Brook 240kV (924L) E4 Nevis 4 to Cordell 4 240kV (9L20) E5 Ware Junction to West Brook 4 240kV (931L) E6 Tilley 7 to West Brook 7 CKT 66 138kV E7 Bellamy 4 to Argyll W CKT 04 240kV E8 Langdon 4 240kV/500kV T1 Transformer E9 Ellersli to Genesee 4 CKT 09 500kV (1209L) E10 Battle River 79 to Cordell 4 CKT 79 240kV E11 Anderson 4 240kV/138 1T Transformer E12 Wint H17 to Bull Pond 7 CKT 85 138kV E13 Gaetz 4 to Red Deer 4 CKT 14 240kV E14 Dome EM 4 to Cypress 2 CKT 11 240kV (945L) E15 Dome EM 7 to Cypress 1 CKT 69 138kV E16 Chappice Lake 7 to Medicine Hat 7 CKT 60 138kV E17 Chappice Lake to Glenridge CKT 58 138kV E18 Cypress 1 to Glenridge CKT58 138kV Comprehensive analysis was performed, but this table reflects problematic contingencies only. Alberta Electric System Operator 479,693 45 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.3.2 S4C2GA - (2012 Summer peak case, 200 MW Wild Rose, 0 MW export to Sask.) Table 5-9 S4C2GA overloaded branches and voltage violations Existing Overloaded % Figure Contingency System element Overload S4GA_N 0 N-0 None 1.094pu - S4GA_E7 E7 Ellersli to Argylle 240kV 100% 102% E8,E13 None (1.135pu, 1.166pu) - E9,E13 None (0.962pu, 0.946pu) - None 1.103pu - None 1.102pu - E10,E11, E12 Many (N-1) E5,E10 None None - Rating A 419MVA Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltage (1.094pu) None Backbone area (500 kV,240kV) over-voltages (1.132pu,1.163pu), high voltage deviation Backbone area (500 kV,240kV) low voltage (0.964pu,0.9495pu) Sheerness area (240kV) over-voltages (1.103pu) Blackie area (138kV) over-voltages (1.103pu) Empress area (240kV) overvoltage (1.10pu) Alberta Electric System Operator 479,693 46 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.3.3 S5C2GA - (2012 Summer peak case, 200 MW Wild Rose, 150 MW import from Sask.) Table 5-10 S5C2GA overloaded branches and voltage violations Figure Conting ency Overloaded element S5GA_N0 N-0 None S5GA_E5 E5 S5GA_E5 E5 S5GA_E5 E5 S5GA_E7 E7 S5GA_E14 S5GA_E15 S5GA_E16 S5GA_E17 S5GA_E18 E14, E15 E16 E17 E18 E8, E13 E9, E13 E10 E11 E12 Many (N-1) E5, E10 Chappice Lake 7 to Medicine Hat 7 138kV Chappice Lake 7 to Glenridge 138kV Cypress 1 to Glenridge 138kV Ellersli to Argylle 240kV 240.00 Empress A7 to Cypress 1 138kV Existing System % Overload Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltage (1.097pu) 1.094pu - None 114% 90MVA None None 122% 90MVA None None 122% 90MVA None 101% 101% 419MV A None None 108% None None None 129.4% 115.4% 100.1% 102.2% 102.3% 90MVA None None (1.135pu, 1.167pu) - None 0.964pu - None 1.103pu - None 1.103pu - None 1.10pu - Backbone area (500 kV,240kV) overvoltages (1.132pu,1.163pu), high voltage deviation Backbone area (500 kV) low voltage (0.97pu) Sheerness area (240kV) over-voltages (1.104pu) Blackie area (138kV) over-voltages (1.104pu) Empress area (240kV) overvoltage (1.10pu) Alberta Electric System Operator 479,693 47 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.3.4 S6C2GA - (2012 Summer peak case, 200 MW Wild Rose, 150 MW export to Sask.) Table 5-11 S6C2GA overloaded branches and voltage violations Existing Contingen Overloaded % Figure System cy element Overload S6GGA_N0 N-0 None S6GA_E7 E7 Ellersli to Argylle 240kV 1.098pu None 101% (1.133pu, 1.165pu) Rating A 419MVA None Backbone area (500 kV,240kV) over-voltages (1.134pu,1.166pu), high voltage deviation Backbone area (500 kV,240kV) low voltage (0.962pu,0.947pu) E8,E13 None E9,E13 None (0.953pu, 0.945pu) - None 1.103pu - Sheerness area (240kV) over-voltages (1.103pu) - Blackie area (138kV) over-voltages (1.102pu) E10, E11, E12 Many (N-1) None 1.105pu - Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltage (1.094pu) Alberta Electric System Operator 479,693 48 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.3.5 S4C2GGA - (2012 Summer peak case, 400 MW Wild Rose, 0 MW export to Sask.) Table 5-12 S4C2GGA overloaded branches and voltage violations Existing Overloaded % Figure Contingency System element Overload S4GGA_N0 N-0 S4GGA_E1 E1 S4GGA_E5 E5 S4GGA_E5 E5 S4GGA_E5 E5 S4GGA_E7 E7 S4GGA_E14 E14, None West Brook 7 to Bassano Tap 138kV Chappice Lake 7 to Medicine Hat 7 138kV Chappice Lake 7 to Glenridge 138kV Cypress 1 to Glenridge 138kV Ellersli to Argylle 240kV Empress A7 to Cypress 1 138kV Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltage (1.093pu) 1.094pu - None 103% 121MV A None None 117% 90MVA None None 125% 90MVA None None 126% 90MVA None 100% 102% 419MV A None None 123% 90MVA None E8, E13 None (1.135pu, 1.166pu) - E9 None 0.962pu - E10, E11, E12 None Many (N-1) None 1.103pu 1.102pu Backbone area (500 kV,240kV) over-voltages (1.1365pu,1.168pu), high voltage deviation Backbone area (500 kV) low voltage (0.962pu) - Sheerness area (240kV) over-voltages (1.103pu) - Blackie area (138kV) over-voltages (1.103pu) Alberta Electric System Operator 479,693 49 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.3.6 S5C2GGA - (2012 Summer peak, 400 MW Wild Rose, 150 MW import from Sask.) Table 5-13 S5C2GGA overloaded branches and voltage violations Existing Contin Overloaded % Figure System gency element Overload Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltage (1.095pu) S5GGA_N0 N-0 None 1.094pu - S5GGA_E1 S5GGA_E2 S5GGA_E4 E1, E2, E4 E1, E5, E6 (More N-1) E1, E5, E6, (More N-1) West Brook 7 to Bassano Tap 138kV None 116% 113% 108% 121MVA None Chappice Lake 7 to Medicine Hat 7 138kV None 107% 151% 110% 90MVA None Chappice Lake 7 to Glenridge 138kV None 115% 159% 118% 90MVA None None 106% 103% 121MVA None 90MVA None S5GGA_E1 S5GGA_E5 S5GGA_E6 S5GGA_E1 S5GGA_E5 S5GGA_E6 S5GGA_E1 S5GGA_E2 E1, E2 Queens Town to Bassano Tap 138kV S5GGA_E1 S5GGA_E5 S5GGA_E6 E1, E5, E6, (More N-1) Cypress 1 to Glenridge 138kV S5GGA_E4 E4 S5GGA_E7 E7 S5GGA_E14 S5GGA_E15 S5GGA_E16 S5GGA_E17 S5GGA_E18 E14, E15, E16, E17, E18 None 116% 160% 118% Nevis 240kV /138kV transformer Ellersli to Argylle 240kV Empress A7 to Cypress 1 138kV E8, E13 None E9 None None 107% 100MVA None 101% 102% 419MVA None None 108% None None None 168.0% 125.6% 114.0% 116.2% 116.4% 90MVA (1.135pu, 1.167pu) 0.964pu - - None Backbone area (500 kV,240kV) overvoltages (1.1360pu,1.167pu), high voltage deviation Backbone area (500 kV) low voltage (0.968pu) Alberta Electric System Operator 479,693 50 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ E10, E11, E12 None Many (N-1) None 1.103pu 1.103pu Sheerness area (240kV) over-voltages (1.103pu) Blackie area (138kV) over-voltages (1.104pu) - - 5.1.3.7 S6C2GGA - (2012 Summer peak, 400 MW Wild Rose, 150 MW export to Sask.) Table 5-14 S6C2GGA overloaded branches and voltage violations Figure S6GGA_ N0 S6GGA_ E7 Overloaded element Existing N-0 None 1.098pu - E7 Ellersli to Argylle 240kV None 102% Contingency E8, E13 None E9 None E10, E11, E12 None Many (N-1) None System (1.133pu, 1.165pu) 0.953pu 1.103pu 1.105pu % Overload - - - - Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) overvoltage (1.094pu) 419MVA None Backbone area (500 kV,240kV) over-voltages (1.1360pu,1.167pu), high voltage deviation Backbone area (500 kV) low voltage (0.963pu) Sheerness area (240kV) over-voltages (1.104pu) Blackie area (138kV) over-voltages (1.103pu) 5.1.4 Powerflow Analysis Summary (2013 SATR) Of the 2013 cases, the worst overloading occurs with the 2013 summer light case with no importing from Saskatchewan (S8C2GGA). For the 2013 summer light cases, the import case from Saskatchewan was not studied. For powerflow simulations with the Wild Rose Wind Farm added, several overloading conditions are evident in the 2013 cases with the SATR upgrades in service: - Empress to Cypress 138 kV Circuit: This line is rated at 90 MVA and is overloaded under several load scenarios and contingencies. The overload is made worse by the addition of the Wild Rose project. The thermal capacity of this line must be upgraded to mitigate these overloads. Alberta Electric System Operator 479,693 51 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ - - - - - Nevis 240/138 kV Transformer: This transformer overloads under certain load conditions when the 240 kV line between Nevis and Cordel is out of service. The overload is made worse by the addition of the Wild Rose project. It is expected that this overload will be mitigated by future cutplane management currently being evaluated by the AESO. Red Deer – Nevis 138 kV Circuit (912L): The dispatch levels for existing area generators in the 2012 “system intact” cases were set at low levels to ease the overloading of the Red Deer to Nevis (912L) transmission line and allow the impact of the full output of the Wild Rose Power Projects to be studied. However, under contingency conditions, this circuit will overload unless generation is further reduced. It is expected that this overload will be resolved by mitigative solutions currently under assessment by the AESO. Janet 240/138 kV Transformer: This is an existing overload condition made marginally worse by the addition of the Wild Rose Wind Farm. (Existing overload 100%, wind added overload 104%). This region is currently being evaluated in a separate study, and overloads will be mitigated as an output of that work. East Calgary 240/138 kV Transformer: This is an existing overload condition made marginally worse by the addition of the Wild Rose Wind Farm. (Existing overload 101%, wind added overload 105%). This region is currently being evaluated in a separate study, and overloads will be mitigated as an output of that work. Janet to East Calgary 240 kV Circuit: A marginal overload (101%) is observed on this line when a circuit between Benalto and Sarcee is out of service under certain loading scenarios. Pre-Wild Rose Generation loading during this contingency is 95%. This region is currently being evaluated in a separate study, and overloads will be mitigated as an output of that work. Note: The generation dispatch assumptions summarized in section 2.3 are critical in ensuring the N-0 (System Intact) scenarios are free of overloads. Altering these dispatch assumptions can cause system intact loading violations, exacerbate contingency overloading violations, and cause new overloading violations. 5.1.5 Special Notes and Assumptions for 2013 Cases 1. Accurate model for 911L Peigan to Janet line is not available for 2013 cases (see section 2.5.6). 2. Capacitor bank operating voltage levels at Calgary area were adjusted to 1.05pu-1.10pu from 0.95pu-1.10pu for 240kV buses and to 1.06pu-1.08pu from 1.00pu-1.05pu for 138kV buses to mitigate the overvoltage and overloading conditions near the Langdon SVC. However, over voltage and overloading conditions are still present for some N-1 contingencies. 3. The Bowmanton 240kV/138kV transformer tap setting was adjusted to match with parallel transformer. Alberta Electric System Operator 479,693 52 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.6 2013 Summer Cases 5.1.6.1 Contingency description for 2013 cases Table 5-15 shows a reduced list of contingencies which may be used for reference in the subsequent tables. Although all contingencies in the regions identified in Table 2-11 were monitored, these contingencies were of particular interest as they exhibited some manner of criteria violation. Table 5-15 2013 contingency description Note 5 Contingency Note 5 Outage element C1 Gaetz 4 to Red Deer 4 CKT 14 240kV C2 Langdon 4 to Milo Junction 240kV (924L) C3 Janet 4 to East Calgary CKT 17 240kV C4 Sarcee 4 to East Calgary CKT 16 240kV C5 Nevis 4 to Cordell 4 240kV (9L20) C6 Ware Junction to West Brook 4 240kV (931L) C7 Langdon 4 240kV/500kV T1 Transformer C8 Stratham to Namakwa 7 CKT 33 138kV C9 Suffield 7 to Tilley 7 CKT 00 138kV (100L) C10 Tilley 7 to West Brook 7 CKT 66 138kV C11 Cavalier 138kV/13.8kV T1 Transformer C12 Cavalier to Namakwa 7CKT 01 138kV C13 Dome EM7 to Oyen CKT 60 138kV (760L) C15 Benalto 4 to Sarcee 4 CKT 28 240kV C16 Dome EM 4 to Cypress 2 CKT 11 240kV (945L) C17 Battle River 79 to Cordell 4 CKT 79 240kV C18 Dome EM 7 to Cypress 1 CKT 69 138kV C19 6Cypress 1 to Glenridge CKT58 138kV Contingency Screening was done and only problematic contingencies are reported. Alberta Electric System Operator 479,693 53 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.6.2 S8C2GGA - ( 2013 Summer Light, 400 MW Wild Rose, 0 MW Import from Sask.) Table 5-16 S8C2GGA overloaded branches and voltage violations Conting ency Overloaded element % Overload N-0 None - S8GGA_N0 N-0 None - S8GGA_C1 C1 S8GGA_C2 S8GGA_C6 C2, C6 S8GGA_C5 C5 Figure Red Deer to Red Deer B 240kV/138kV T2 Transformer (See note 2) Red Deer to Nevis 240kV (912L) Nevis 240kV /138kV transformer Rating A Other system performance concerns (Maximum reported) Backbone area (500kV) Overvoltage (1.101pu)1 Blackie area (138kV) over-voltages (1.086pu) 119% 200 MVA None 105%, 104% 488MVA None 155% 100MVA None C7 None - Backbone area (500 kV,240kV) over-voltages (1.109pu,1.139pu), high voltage deviation C8 None - Blackie area (138kV) high voltage deviation Additional Notes: 1. Genesee generation step up transformer tap ratios may be adjusted to 1.00 from 1.06 to mitigate overvoltage issues at Genesee buses (525). 2. Red Deer Transformer overload is due to a VAR looping condition in the power flow case. This overload can be eliminated by adjusting transformer tap settings. Alberta Electric System Operator 479,693 54 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.6.3 S9C2GGA - (2013 Summer peak, 400 MW Wild Rose, 0 MW import from Sask.) Table 5-17 S9C2GGA overloaded branches Figure Contingency Overloaded element % Overload Rating A Other system performance concerns (Maximum reported) Blackie area (138kV) over-voltages (1.092pu) S9GGA_N0 N-0 None - S9GGA_C3 C3 Janet 4 to Janet 7 240kV/138kV T1 Transformer 104% 2X 400MVA Calgary (240kV) high voltage deviation S9GGA_C4 C4 East Calgary Enmax2S7 240kV/138kV T1 Transformer 104% 336MVA None Backbone area (500 kV,240kV) overvoltages (1.137pu,1.168pu), high voltage deviation Medicine Hat and Brooks areas (138kV) low voltages( 0.948pu,0.939pu), high voltage deviation C7 None - C9, C10 None - C11,12 None - Blackie area (138kV) high voltage deviation C13 None - Empress (138kV) high voltage deviation Alberta Electric System Operator 479,693 55 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.6.4 S10C2GGA - (2013 Summer peak, 400 MW Wild Rose, 150 MW import from Sask.) Table 5-18 S10C2GGA overloaded branches Figure Contingency Overloaded element % Overload A10GGA_N0 N-0 None - S10GGA_C3 C3 S10GGA_C4 C4 S10GGA_C5 C5 S10GGA_C15 C15 S10GGA_C16 S10GGA_C17 S10GGA_C18 S10GGA_C19 C16, C17, C18, C19 Janet 4 to Janet 7 240kV/138kV T1 Transformer East Calgary Enmax2S7 240kV/138kV T1 Transformer Rating A Other system performance concerns (Area) Blackie area (138kV) over-voltages (1.0923pu) 106% 2X 400MVA Calgary (240kV) high voltage deviation 105% 336MVA None Nevis 240kV /138kV transformer 108% 100MVA None Janet 4 to East Calgary 17 101% 478MVA None 121.5%, 101.7%, 129.8%, 106.8% 90MVA None Empress A7 to Cypress 1 138kV C7 None - Backbone area (500 kV,240kV) overvoltages (1.137pu,1.169pu), high voltage deviation C9, C10 None - Medicine Hat, Brooks areas (138kV) high voltage deviation C11,12 None - Blackie area (138kV) high voltage deviation C13 None - Empress area (138kV) high voltage deviation Alberta Electric System Operator 479,693 56 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.1.7 Reactor Design 5.1.7.1 Summary Base cases for 2012 and 2013 were studied for compliance with operating voltage regulations in the Wild Rose area and sizing of additional shunt reactance as needed. A 50 MVAR shunt reactor is required to mitigate overvoltage violations on the 240 kV path from Cypress to Wild Rose in the 2012 case. The 2013 case has significant topology differences, including an SVC at Whitla, such that the overvoltage violations do not occur. No reactor is required after the 2013 upgrades have been added. 5.1.7.2 2012 Configuration The Wild Rose wind power plant is radially connected to the Cypress substation in the 2012 configuration. See Figure 5-1 Study area in 2012 cases. Figure 5-1. Figure 5-1 Study area in 2012 cases. Overvoltage conditions occur during energization of the 240 kV path from Cypress to Wild Rose. Of the 2012 cases studied, the worst overvoltage violations occur with the 2012 summer light case with 150 MW importing from Saskatchewan. 5.1.7.3 Line Energization Voltage Violations (2012) In Table 5-19, overvoltage conditions are shown during sequential line energization from Cypress to Wild Rose. The respective voltage levels with 45 MVAR and 50 MVAR shunt reactors added are shown in last two columns. Overvoltage conditions occur at the Bowmanton 240 kV bus during initial energization of the Cypress to Bowmanton line. Bowmanton was therefore selected as the site of the Switched Reactor. Alberta Electric System Operator 479,693 57 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ A 50 MVAR shunt reactor connected at Bowmanton is sufficient to keep the voltage below 1.1 pu during energization of the lines. Since the pre-fault voltage (1.1pu) must be the same as the post fault voltage, the reactor must 100 % compensate the charging on the line, which is approximately 50 MVARs. Table 5-19 Line Energization Voltage Levels Bus Energization voltage (pu) during sequential energization (No reactor added) Voltage Measuring Location Voltage after Reactor Addition (pu) (Entire path energized*) Pre Energization Line energized to Bowmanton Line energized to Elkwater** Entire path energized to Wild Rose* With 45 MVAR Reactor at Bowmanton With 50 MVAR Reactor at Bowmanton 1.100 1.110 1.128 1.134 1.102 1.099 Bowmanton 240kV N/A 1.115 1.153 1.163 1.099 1.092 Elkwater 240kV N/A N/A 1.155 1.167 1.102 1.096 Wild Rose 240kV N/A N/A N/A 1.168 1.103 1.097 Anderson 240kV 1.087 1.089 1.092 1.093 1.088 1.087 Cypress 240kV *No Wild Rose wind generation in service **Both lines from Bowmanton to Elkwater connected 5.1.7.4 Voltage violations during no-wind conditions (2012) No overvoltage conditions are observed when the entire path is energized and the wind farm is connected but no wind is blowing. The voltage levels with no-wind blowing conditions are shown in Table 5-20. For the no-wind condition, no reactor is required provided the wind turbines are in service. Table 5-20 Voltage Levels with wind farm full power and wind farm connected to the grid Voltage (pu) Wind Farm at Full Power No Reactor Wind Farm Energized (Zero wind) No Reactor Cypress 240kV Bowmanton 240kV Elkwater 240kV 1.062 1.046 1.048 1.095 1.084 1.078 Wild Rose 240kV 1.050 1.070 Anderson 240kV 1.073 1.086 Voltage Measuring Location 5.1.7.5 2013 Configuration The 2013 cases present two significant topology changes from the 2012 cases: there is a new double circuit 240 kV line connecting Bowmanton to West Brooks and there is a new 240 kV double circuit connecting Elkwater to Whitla (SUBD1). Whitla is the site of a 125 MVAR SVC. See Figure 5-2. Alberta Electric System Operator 479,693 58 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Figure 5-2 Study area in 2013 cases. With this network configuration, the wind farm is no longer radially connected from Cypress, and the connections to West Brooks and Whitla contribute to maintaining the voltage profile during the energization of the pertinent line segments. Therefore, reactor will be of minimal use after the 2013 upgrades have been added. 5.1.7.6 Additional Shunt Reactor Notes 1. During no wind blowing conditions, the line side convertor of the AW1500 wind generator has the limited capability to consume 300 kVAr according to the "Electric Grid Data AW 1500+ (DG178022-M) " document. This capability is reflected in the results above. 2. The reactor capacities are specified at a rated voltage of 1.0 pu. However, reactors are operated at a voltage closer to 1.1 pu. Therefore, actual inductive reactive power is higher than the rated value. 3. The 2*24 MVAR capacitor bank at 267 Dome Empress (138 kV) and 2*24.8 MVAR capacitor bank at McNeil are switched off during the reactor design to keep analysis consistent with wind farm in service and out of service conditions. 4. The following loads were switched off to raise the Cypress voltage to 1.1 pu before line energization. Alberta Electric System Operator 479,693 59 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 5-21 Table of loads switched out to keep Cypress voltage at 1.1 pu Load Bus PSSE 2260 3260 4260 4986 2053 3053 4266 4111 JENNERA9 JENNERB9 JENNERC9 JENNERD9 SANDYPA9 SANDYPB9 EMPRESS9 SANDHIL9 Area 25.000 25.000 25.000 25.000 4.7000 4.7000 25.000 13.800 Total 48 48 48 48 48 48 48 48 EMPRESS EMPRESS EMPRESS EMPRESS EMPRESS EMPRESS EMPRESS EMPRESS Load (MW) 11.8 11.8 11.8 11.8 3.4 3.4 6.3 33.2 93.5 (MVAR) 3.8 3.8 3.8 3.8 1.2 1.2 2.1 0 19.7 5.2 Stability Analysis 5.2.1 Stability Analysis Summary Dynamic analysis was performed using PSS/E version 30.3.3. For each of the base cases analyzed, a set of 36 contingencies was applied, including selected Category B and C disturbances. The primary goal of these studies is to determine whether the system remains dynamically stable under fault and outage conditions, but each run was examined for additional concerns, such as post-fault voltage, AVR operation, machine tripping, poorly damped oscillations, and any other problematic behaviour. The assumptions and additional observations discussed in section 2.5.7 apply for “wind added” analysis. Specific dynamic concerns identified with the “wind added” system are: 1. Existing Castle, MacBride, Kettles, and Summerview wind farms experience tripping in some contingencies. This is due to under-voltage protection operation. This tripping may not be realistic, as these wind farms are modeled in a fixed Q mode, and using obsolete models. The tripping is evident in the existing system and is not impacted significantly by the addition of the Wild Rose plant. 2. Loss of the double circuit line (N-2) between Cypress and Ware Junction leaves the Empress area in a very weak condition, and depending on the status of the McNeil DC tie can result in load/generation imbalance in the area. This imbalance may be sufficient to cause instability. This condition is not eliminated by the addition of Wild Rose wind farm in 2012, but the generation/load balance does change depending on wind levels. In 2013, it is expected that this problem will be eliminated due to the strengthened ties into the Empress area, but until these upgrades are implemented, a fast reduction in power from the wind farm or cross-trip may be required when both circuits from Cypress to Ware Junction are lost. Alberta Electric System Operator 479,693 60 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3. While the system is capable of sustaining SLG faults with long clearing times (during fault-andcommon-breaker-fail events), many breaker fail events cause instability if the fault type is LLLG instead of SLG. The addition of the Wild Rose plant does not affect this condition. 4. The 2012 cases studied here do not exhibit dynamic instability due to the loss of lines south from Anderson. The cases use the same dispatch assumptions as the steady state analysis, that being the existing area units operating under reduced power to prevent overloading on the Red-Deer Nevis circuit. North-South powerflow through Anderson is reduced, and the loss of this circuit no longer causes instability under these conditions. However, for the 2012 cases the Wild Rose wind farm is more susceptible to tuning parameters and model limitations for these conditions and will trip depending on control tuning. For the 2013 cases with existing area generation at full power, the instability is still evident. The Wild Rose plant does not improve this condition. 5. A fault at West Brooks followed by the loss of both of the Milo – West Brooks line in the 2013 cases (Category C) exhibits poorly damped or unstable conditions. This is related to the same instability indicated above with the loss of the line(s) through Anderson, interrupting the path south from Sheerness and causing additional power to flow North from Sheerness and Battle River. This has been identified by AESO studies as an existing problem. 6. An N-1-1 contingency where the line from Nevis to Red Deer is lost following the loss of the line from Langdon to Milo Junction exhibits poor stability, sensitive to the specific control parameters set in the Wild Rose wind farm. Control parameter selections used in this analysis indicate stable operation. Except for the above mentioned issues, all cases maintain stability and good voltage profiles within a few seconds following the fault. It is noted that in 2012, the wind farm is radially connected into Cypress, and the short circuit ratio (SCR, or ratio of plant MVA to network SCMVA) at the wind farm is relatively low. The Wild Rose turbines are of a DFIG type, which may be vulnerable to performance issues in weak systems such as this. Such issues fall outside the requirements of this analysis and will be examined separately by NEC. Alberta Electric System Operator 479,693 61 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.2.2 Contingency description Table 5-22 shows a list of contingencies and events which were applied for all dynamic analysis cases. Table 5-22 List of Outages and Events Applied for Dynamic Analysis Contingency Reference # Elements Outage Fault Fault Location (line end) CAT B (N-1) C1 1009L - from Bowmanton to Cypress 3LG East Medicine Hat Substation C2 945L or 951L - from Cypress to Jenner 3LG Cypress 240kV Substation - 562S C3 944L - from Jenner to Ware Junction 3LG Ware Jct 240kV Substation -132S C4 931L - from Ware Junction to W.Brook 3LG Ware Jct 240kV Substation -132S C5 9L 933 - from Anderson to W.Brook 3LG Anderson 240kV Substation -801S C6 9L 933 - from Anderson to W.Brook 3LG West Brooks 240kV Substation - 28S C7 9L950 or 9L934 - from Ware Junction to Anderson 3LG Ware Junction 240kV Substation - 132S C8 9L950 or 9L934 - from Ware Junction to Anderson 3LG Anderson 240kV Substation - 801S C9 923L or 924L - from W. Brook to N.Lethbridge ( Milo for 2013 cases) 3LG West Brooks 240kV Substation - 28S C10 Amoco Empress 163S (240/138kV transformer) 3LG Amoco Empress 240kV Substation -163S C11 830L - from Cypress 562S to McNeill 840S 3LG Cypress 138kV Substation -562S C12 Elkwater to WR1 (Loss of 200MW) 3LG Elkwater Substation C13 Elkwater to WR2 (Loss of 200 MW) 3LG Elkwater Substation C14 One circuits lost between Bowmanton and Elkwater 3LG Bowmanton C15 Sudden loss of all 400 MW wind N/A N/A C16 1034L or 1035L - from Bowmanton to W.Brook (2013 only) 3LG Bowmanton C16B Rd Deer to Nevis 3LG Red Deer240kV Substation CAT C (N-2) C17 945L/951L - from Cypress to Jenner 3LG Cypress 240kV Substation - 562S C18 944L - from Jenner to Ware Junction 3LG Ware Jct 240kV Substation -132S C19 9L950/9L934 - from Ware Junction to Anderson 3LG Anderson 240kV Substation -801S C20 9L950/9L934 - from Ware Junction to Anderson 3LG Ware Junction 240kV Substation - 132S C21 923L/924L - from W. Brook to N.Lethbridge (Milo for 2013 cases) 3LG West Brooks 240kV Substation - 28S C22 1034L/1035L -from Bowmanton to W.Brook 3LG Bowmanton C23 Both circuits lost between Bowmanton and Elkwater 3LG Bowmanton C24 Line West towards Withla/Lethbridge (both lines) 3LG Elkwater Substation Breaker Failure Contingencies ( Delayed clearing time 18cycles) C25 Janet to Red Deer std time and Janet to Langdon delayed 1LG Janet 240kV Substation C26 Janet to Red Deer std time and trip Janet to Peigan delayed 1LG Janet 240kV Substation C27 Langdon to Milo std time and Langdon to Janet delayed 1LG Langdon 240kV Substation C28 1LG Langdon 240kV Substation C29 Langdon to Janet std time and Langdon SVC delayed time West Brooks to Milo Junction std time and West Brooks to Ware Junction delayed time 1LG West Brooks 240kV Substation - 28S C30 Red Deer to Gaetz std time and Red Deer to Nevis delayed time 1LG Red Deer 240kV Substation C31 Nevis to Cordel std time and Nevis to Red Deer delayed time 1LG Nevis 240kV Substation C32 Cordel to Nevis std time and BR Unit 5 delayed time 1LG Cordel 240kV Substation C33 1LG Anderson 240kV Substation C35 Anderson to West Brooks std time and SH Unit 1 delayed time Ware Junction to Jenner std time and Ware Junction to West Brooks delayed time Jenner to Amoco Empress std time and Jenner to Ware Junction delayed time C36 Langdon to Milo std time and Nevis to Red Deer delayed time C34 1LG 1LG Ware Junction 240kV Substation - 132S Jenner 240kV Substation N-1-1 contingencies ( 2nd fault and outage after 1st outage reaches steady state) 3LG Red Deer 240kV Substation Alberta Electric System Operator 479,693 62 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.2.3 2012 (Pre-SATR) Cases 5.2.3.1 S1C2GGA - ( 2012 Summer Light case, 400 MW Wild Rose, 0 MW export to Sask.) Table 5-23 2012 Summer Light Case with no Saskatchewan Import and 400 MW Wild Rose wind C1 C2 C3 C4 C5 C6 C7 C8 C9 C10 C11 Existing System Stable? N/A √ √ √ √ √ √ √ √ √ √ S1C2GGA: WR Case Expected Stable? √ √ √ √ √ √ √ √ √ √ √ C12 N/A √ C13 N/A √ C14 C15 C16 C16B C17 N/A N/A N/A √ X √ √ N/A √ X X X √ √ √ N/A N/A N/A √ √ √ √ √ √ √ √ √ √ √ √ √ √ √ N/A √ N/A √ √ √ √ √ √ √ √ √ √ √ √ Contingency N-1 N-2 Breaker fail (SLG 18cycle) N-1-1 C18 C19 C20 C21 C22 C23 C24 C25 C26 C27 C28 C29 C30 C31 C32 C33 C34 C35 C36 400 MW Wind Added - 2012 Light Load (Pre-SATR) with no McNeil activity Comments No tripping No tripping 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) (With 2 Mode Changes) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,11 - KETTLES Tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,11 - KETTLES Tripped (VTGTPTA - UV) No tripping No tripping OV, with slow recovery to 1.1pu, May be fixed by wind farm tuning, but Bowmanton reactor may need to be switched in until wind farm AVR can respond. OV, with slow recovery to 1.1pu, May be fixed by wind farm tuning, but Bowmanton reactor may need to be switched in until wind farm AVR can respond. No tripping Overvoltage occurs unless Bowmanton reactor is switched in (See reactor sizing study) N/A 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) Unstable - Loss of 2 ccts from Empress to WJ result in too much generation at Empress (use x-trip) Weak System: See comment C17, but system stays together with wind farm control oscillations. Xtrip probably required for backup. 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,11 - KETTLES Tripped (VTGTPTA - UV) N/A No tripping N/A No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping No tripping 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) Alberta Electric System Operator 479,693 63 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.2.3.2 S5C2GGA - (2012 Summer peak, 400 MW Wild Rose, 150 MW import from Sask.) Table 5-24 2012 Summer Peak Case with 150 MW Saskatchewan Import and 400 MW Wild Rose wind Contingency C1 C2 C3 C4 C5 C6 C7 C8 N-1 C9 C10 C11 C12 C13 C14 C15 C16 C16B C17 C18 C19 C20 N-2 Breaker fail (SLG 18cycle) N-1-1 C21 C22 C23 C24 C25 C26 C27 C28 C29 C30 C31 C32 C33 C34 C35 C36 S5C2GGA: 400 MW Wind Added - 2012 Heavy Load (Pre-SATR) with 150 MW McNeil import Existing WR Case System Expected Comments Stable? Stable? N/A √ No tripping √ √ No tripping √ √ 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) √ √ 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) √ √ 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,11 - KETTLES Tripped (VTGTPTA - UV), WR √ √ tripped due to model problem in weak system (Can be solved by adjusting DYR parameters, but this is a known weak system condition due to loss of Anderson line) Use Bowmanton Reactor √ √ 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) √ √ 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,11 - KETTLES Tripped (VTGTPTA - UV), WR tripped due to model problem (Can be solved by adjusting DYR parameters, but this is a weak system √ √ condition due to loss of line from West Brooks to Lethbridge) Use Bowmanton Reactor √ √ No tripping √ √ No tripping OV, with slow recovery to 1.1pu, May be fixed by wind farm tuning, but Bowmanton reactor may N/A √ need to be switched in until wind farm AVR can respond. OV, with slow recovery to 1.1pu, May be fixed by wind farm tuning, but Bowmanton reactor may N/A √ need to be switched in until wind farm AVR can respond. N/A √ No tripping N/A √ Overvoltage occurs unless Bowmanton reactor is switched in (See reactor sizing study) N/A N/A N/A √ √ 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) √ X Unstable - Loss of 2 ccts from Empress to WJ result in too much generation at Empress (use x-trip) √ X Unstable - Loss of 2 ccts from Empress to WJ result in too much generation at Empress (use x-trip) √ √ 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) √ √ 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV), WR trip Same comment as C6 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8- KETTLES Tripped (VTGTPTA - UV), WR tripped √ √ (same comment as C6) N/A N/A N/A N/A √ No tripping N/A N/A N/A √ √ No tripping √ √ No tripping √ √ No tripping √ √ No tripping √ √ No tripping √ √ No tripping √ √ No tripping √ √ No tripping √ √ No tripping √ √ No tripping √ √ No tripping √ √ 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) Alberta Electric System Operator 479,693 64 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.2.4 2013 (SATR) Cases 5.2.4.1 S8C2GGA - ( 2013 Summer Light, 400 MW Wild Rose, 0 MW Import from Sask.) Table 5-25 2013 Summer Light Case with no Saskatchewan Import and 400 MW Wild Rose wind S8C2GGA: 400 MW Wind Added - 2013 (SATR) Light Load with no Mcneil activity Contingency N-1 N-2 Breaker fail (SLG 18cycle) N-1-1 WR Case Expected Stable? C1 C2 C3 C4 C5 C6 C7 C8 C9 C10 C11 C12 C13 C14 C15 C16 C16B C17 C18 C19 C20 √ √ √ √ X √ √ X √ √ √ √ √ √ √ √ √ √ √ X X C21 √ C22 C23 C24 C25 C26 C27 C28 C29 C30 C31 C32 C33 C34 C35 C36 √ √ √ √ √ √ √ √ √ √ √ √ √ √ √ Comments 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) Unstable (Loss of Anderson to WB line) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,9,11,12 - KETTLES Tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) Unstable (Loss of Anderson to WJ line) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,9,11,12 - KETTLES Tripped (VTGTPTA - UV) No Tripping No Tripping No Tripping No Tripping 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) No Tripping 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100001,2 - CASTLE, 3,4,5 - MACBRIDE, 6,7 - SUMMERG, 8,9, - KETTLES Tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) Unstable (2 cct outage from WJ to Anderson) Unstable (2 cct outage from WJ to Anderson) Poor damping - Oscillations last 15 seconds, 100001,2-CASTLE, 3,4,5-MACBRIDE, 6,7-SUMMERG, 8,9,11,12-KETTLES Tripped 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) 100003,4,5 - MCBRIDE tripped (VTGTPTA - UV) No Tripping No Tripping No Tripping No Tripping No Tripping No Tripping No Tripping No Tripping No Tripping No Tripping No Tripping No Tripping 100001,2 - CASTLE, 6 - SUMMERG Tripped (VTGTPTA - UV) Alberta Electric System Operator 479,693 65 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.2.4.2 S10C2GGA - (2013 Summer peak, 400 MW Wild Rose, 150 MW import from Sask.) Table 5-26 2013 Summer Peak Case with 150 MW Saskatchewan Import and 400 MW Wild Rose wind S10C2GGA: 400 MW Wind Added - 2013 (SATR) Heavy Load with 150 MW Mcneil import WR Case Contingency Expected Comments Stable? C1 √ 100003,4,5 - Wind generators at MCBRIDE tripped C2 √ 100003,4,5 - Wind generators at MCBRIDE tripped C3 √ 100003,4,5 - Wind generators at MCBRIDE tripped C4 √ 100003,4,5 - Wind generators at MCBRIDE tripped C5 X Unstable (Loss of Anderson to WB line) C6 √ 100001,2,3-CASTLE, 3,4,5-MACBRIDE, 6,7-SUMMERG, 8,9-KETTLES Tripped C7 √ 100003,4,5 - Wind generators at MCBRIDE tripped C8 X Unstable (Loss of Anderson to WJ line) N-1 C9 √ 100001,2-CASTLE, 3,4,5-MACBRIDE, 6,7-SUMMERG, 8,9-KETTLES Tripped C10 √ 100003,4,5 - Wind generators at MCBRIDE tripped C11 √ No tripping C12 √ No tripping C13 √ No tripping C14 √ 100003,4,5 - Wind generators at MCBRIDE tripped C15 √ No tripping C16 √ 100003,4,5 - Wind generators at MCBRIDE tripped C16B √ 100003,4,5 - Wind generators at MCBRIDE tripped C17 √ 100003,4,5 - Wind generators at MCBRIDE tripped C18 √ 100003,4,5 - Wind generators at MCBRIDE tripped C19 X Unstable (2 cct outage from WJ to Anderson) C20 √ 100003,4,5-MACBRIDE, 97559,60 - IP - 634 Tripped N-2 Under damped - Oscillations last 15 seconds, 100001,2-CASTLE, 3,4,5-MACBRIDE, 6,7-SUMMERG, √ C21 8,9-KETTLES Tripped C22 √ 100003,4,5 - Wind generators at MCBRIDE tripped C23 √ 100003,4,5 - Wind generators at MCBRIDE tripped C24 √ No tripping C25 √ No tripping C26 √ No tripping C27 √ No tripping C28 √ No tripping Breaker C29 √ No tripping fail (1LG - C30 √ No tripping 18cycle) C31 √ No tripping C32 √ No tripping C33 √ No tripping C34 √ No tripping C35 √ No tripping N-1-1 C36 √ No tripping Alberta Electric System Operator 479,693 66 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 5.3 Short Circuit Analysis - Wind added System A short circuit study was performed using the Summer Peak cases with 150MW import from Saskatchewan (Case designation S5C2GA,S5C2GGA and S10C2GGA) to simulate the worst case short circuit faults in wind added systems. 5.3.1 Short Circuit Analysis Results – 2012 (Pre-SATR) The results for the wind added system analysis are shown in Table 5-27 and Table 5-28. Table 5-27 2012 Summer Peak Case with 150MW Saskatchewan Import and 200 MW Wild Rose Wind 2012 Summer Peak Case with 150MW Saskatchewan Import and 100MW BC Export (With Wild Rose 1, 200 MW, S5C2GA) Positive Seq Zthev Zero Seq Zthev Pre Base 3LG SLG (pu) (pu) Fault Fault Location Voltage Fault Fault Voltage (kV) (kA) (kA) R jX R jX (pu) 1.0735 10.534 0.00388 0.02421 8.164 0.00928 0.04396 Ware Junction 240 240 1.0740 6.990 0.00561 0.03654 4.599 0.02203 0.09243 Amoco Empress 240 1.0698 5.981 0.00496 0.04274 3.976 0.02674 0.10728 West Brooks 138 1.0325 13.131 0.00718 0.03210 13.671 0.00218 0.02872 Elkwater 240 1.0542 2.431 0.00935 0.10392 2.534 0.02271 0.09945 West Brooks 240 1.0540 10.814 0.00479 0.02295 11.339 0.00203 0.01959 Bowmanton 240 1.0574 2.687 0.00852 0.09428 2.654 0.02345 0.10411 Cypress 1 138 1.0231 8.748 0.00488 0.04868 6.408 0.02508 0.10296 Cypress 2 240 1.0701 5.959 0.00504 0.04290 4.048 0.02592 0.10371 Medicine Hat 138 0.9959 5.394 0.02310 0.07371 5.457 0.00817 0.07568 Sheerness 240 1.0859 12.562 0.00237 0.02066 12.546 0.00187 0.01846 Anderson 240 1.0853 12.892 0.00234 0.02012 13.009 0.00171 0.01737 Jenner Alberta Electric System Operator 479,693 67 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 5-28 2012 Summer Peak Case with 150MW Saskatchewan Import and 400 MW Wild Rose Wind 2012 Summer Peak Case with 150MW Saskatchewan Import and 100MW BC Export (With Wild Rose 1 and Wild Rose 2, 400 MW, S5C2GGA) Positive Seq Zthev Zero Seq Zthev Pre Base 3LG SLG (pu) (pu) Fault Fault Location Voltage Fault Fault Voltage (kV) (kA) (kA) R jX R jX (pu) 1.0715 10.603 0.00386 0.02400 8.222 0.00922 0.04363 Ware Junction 240 Jenner 240 1.0745 7.122 0.00551 0.03587 4.714 0.02148 0.09004 Amoco Empress 240 1.0749 6.214 0.00478 0.04134 4.206 0.02530 0.10091 West Brooks 138 1.0297 13.117 0.00717 0.03205 13.658 0.00218 0.02869 Elkwater 240 1.0577 2.851 0.00737 0.08894 3.634 0.00461 0.04453 West Brooks 240 1.0502 10.813 0.00478 0.02287 11.338 0.00203 0.01957 Bowmanton 240 1.0560 3.063 0.00703 0.08263 3.661 0.00594 0.05252 Cypress 1 138 1.0385 8.956 0.00486 0.04827 6.679 0.02391 0.09903 Cypress 2 240 1.0749 6.208 0.00483 0.04138 4.307 0.02423 0.09678 Medicine Hat 138 1.0081 5.397 0.02363 0.07448 5.466 0.00839 0.07640 Sheerness 240 1.0845 12.593 0.00237 0.02058 12.574 0.00187 0.01845 Anderson 240 1.0839 12.925 0.00233 0.02004 13.042 0.00171 0.01735 5.3.2 Short Circuit Analysis Results – 2013 (SATR) The results for the wind added system analysis are shown in Table 5-29. Table 5-29 2013 Summer Peak Case with 150MW Saskatchewan Import and 400 MW Wild Rose Wind 2013 Summer Peak Case with 150MW Saskatchewan Import and 100MW BC Export (With Wild Rose 1 and Wild Rose 2, 400 MW, S10C2GGA) Positive Seq Zthev Zero Seq Zthev Pre Base 3LG SLG (pu) (pu) Fault Fault Location Voltage Fault Fault Voltage (kV) (kA) (kA) R jX R jX (pu) 1.0761 10.576 0.00403 0.02414 8.179 0.00933 0.04426 Ware Junction 240 Jenner 240 1.0750 7.318 0.00581 0.03486 4.744 0.02156 0.09050 Amoco Empress 240 1.0711 6.997 0.00467 0.03653 4.438 0.02498 0.09883 West Brooks 138 1.0364 12.688 0.00712 0.03343 13.642 0.00186 0.02709 Elkwater 240 1.0678 5.470 0.00621 0.04655 6.749 0.00317 0.02375 West Brooks 240 1.0574 11.439 0.00451 0.02178 12.478 0.00176 0.01654 Bowmanton 240 1.0696 7.038 0.00546 0.03615 7.944 0.00336 0.02581 Cypress 1 138 1.0428 9.403 0.00503 0.04612 6.714 0.02491 0.10185 Cypress 2 240 1.0715 7.078 0.00466 0.03611 4.579 0.02399 0.09448 Medicine Hat 138 1.0112 7.029 0.00814 0.05963 6.708 0.00834 0.06967 Sheerness 240 1.0906 12.535 0.00247 0.02078 12.233 0.00206 0.02019 Anderson 240 1.0898 12.864 0.00244 0.02023 12.631 0.00196 0.01930 Alberta Electric System Operator 479,693 68 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 6.0 Summary and Conclusions 6.1 Summary - Powerflow Analysis Powerflow analysis performed herein evaluated 21 base case scenarios encompassing existing system cases, 2012 (pre-SATR) wind added cases, and 2013 (post-SATR) wind added cases with a complete set of Category A and B contingencies. The violations observed in all these cases may be categorized as one of three types: - - Local violations requiring RAS or network upgrades. Many of these concerns are addressed by the addition of the 2013 SATR network upgrades. External violations which are remote from the wind farm connection, and are currently under examination in other studies. Those studies are expected to propose resolutions for the specific violations identified. System wide concerns involving load/generation/interchange sensitivities, which may be mitigated using operational practices or cut-plane management. In addition, a planned NorthSouth HVDC line is expected to assist in mitigating these system constraints. A selected set of Category C contingencies has been studied, and these results are reported in Appendix B (not reflected in this summary). A summary of the worst power flow violations are presented in Table 6.1. 6.1.1 Local Violations Local violations requiring RAS or network upgrades include the following overloads: - - - Empress to Cypress 138 kV Circuit: This line is rated at 90 MVA and is overloaded under several load scenarios and contingencies. The overload is made worse by the addition of the Wild Rose project. The thermal capacity of this line will be up-rated as the part of the scope of this project. West Brooks – Bassano Tap – Queenstown 138 kV Circuit: The addition of the Wild Rose Wind Farm overloads this circuit under contingency conditions. A RAS scheme exists to manage this overload, and should be extended to account for the Wild Rose project. It is expected that the SATR upgrades and projects proposed for the Blackie area will mitigate this overload. Medicine Hat – Suffield 138 kV Circuit, and Medicine Hat – Chappice Lake – Glenridge – Cypress 138 kV Circuit: The 138 kV network around Medicine hat is stressed by the addition of any injection of power in the Cypress/Empress area, including Wild Rose and the McNeil DC tie. Wind connecting into the 138 kV system around Medicine Hat also stresses this network, causing overloads under contingency conditions. It is expected that the SATR network upgrades (2013) will mitigate these overloads with the reconnection of the 138 kV system at Medicine Hat. In the interim period RAS must be implemented to reduce imports through McNeil or other generator power in the case of the specific contingencies causing the overloads. Alberta Electric System Operator 479,693 69 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 6.1.2 Remote Violations The following violations are relatively remote from the Wild Rose wind farm: Calgary area violations: The Calgary region encompassing these overloads are currently being evaluated in a separate study, and overloads will be mitigated as an output of that work: - Janet 240/138 kV Transformer: This is an existing overload condition made marginally worse by the addition of the Wild Rose Wind Farm. - Janet to Peigan (911L) line: This circuit is overloaded under N-0 conditions in the existing system, and overloading becomes worse during N-1 contingencies. This overload is made worse by the addition of the Wild Rose Wind Farm, and is expected to be mitigated by the planned upgrades to 911L. - East Calgary 240/138 kV Transformer: This is an existing overload condition made marginally worse by the addition of the Wild Rose Wind Farm. - Janet to East Calgary 240 kV Circuit: A marginal overload (101%) is observed on this line when a circuit between Benalto and Sarcee is out of service under certain loading scenarios. The improvements planned for the Calgary Area associated with the Foothills development and other projects are expected to remove the above violations. Elerslie to Argyle 240 kV Circuit: This overload is primarily due to high VAR flows stemming from poor power factor on lines in the Wabamun generation area. VAR management in this region may be adequate to mitigate this problem. This region is far away from the Wild Rose project area, and this overload is not substantially impacted by the addition of the new wind generation. 6.1.3 System-Wide Concerns The following concerns are dependent on system wide generation and load dispatch conditions. An AESO overall system management study is ongoing which will discuss mitigation and prevention of these overload conditions. - Nevis 240/138 kV Transformer: This transformer overloads under certain load conditions when the 240 kV line between Nevis and Cordel is out of service. The overload is made worse by the addition of the Wild Rose project. The study shows as much as a 155% overload under certain conditions. - Red Deer – Nevis 138 kV Circuit (912L): The dispatch levels for existing generators in the 2012 “system intact” cases were adjusted to ease the overloading of the Red Deer to Nevis (912L) transmission line and allow the impact of full output of the Wild Rose Power Project to be studied. However, under contingency conditions, this circuit will overload unless generation is further reduced. Langdon to Janet 240 kV Path: Under certain generation dispatch levels and contingencies this path may experience overloading. - Alberta Electric System Operator 479,693 70 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 6-1 Summary of Worst Powerflow Violations (see table footnote) Base Case & Figure Contingency Overloaded element Existing System % Overload Rating A Other system performance concerns (Maximum reported) S2GGA_D18 D18 Empress A7 to Cypress 1 138kV 129% 184% 90MVA None S2GGA_D4 D4 None 127% 121MVA None S2GGA_D4 D4 None 118% 121MVA None S2GGA_D1 D1 None 121% 67MVA None S5GGA_E5 E5 None 151% 90MVA None S5GGA_E5 E5 Chappice Lake 7 to Glenridge 138kV None 159% 90MVA None S5GGA_E5 E5 Cypress 1 to Glenridge 138kV None 160% 90MVA None S10GGA_C3 C3 Janet 4 to Janet 7 240kV/138kV T1 Transformer None 106% 2X 400MVA Calgary (240kV) high voltage deviation S10GGA_C4 C4 East Calgary Enmax2S7 240kV/138kV T1 Transformer None 105% 336MVA None S10GGA_C15 C15 Janet 4 to East Calgary 17 None 101% 478MVA None S8GGA_C5 C5 Nevis 240kV /138kV transformer None 155% 100MVA None S2GGA_C1 D1 Red Deer to Nevis 240kV (912L) None 109% 488MVA None West Brook 7 to Bassano Tap 138kV Queens Town to Bassano Tap 138kV Suffield 7 to Medicine Hat 7 138kV (892L) Chappice Lake 7 to Medicine Hat 7 138kV Note: The violations indicated in this table represent the conditions producing the worst overload on a given element. Other conditions or contingencies can produce lesser overloads on these elements. See tables in the Chapters 3 and 5 for complete list of contingencies capable of causing element overloading. Alberta Electric System Operator 479,693 71 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 6-2 Contingency description for worst powerflow violations Contingency Outage element D1 & E5 D4 D18 C3 C4 C5 C15 Ware Junction to West Brook 4 240kV (931L) Red Deer to Nevis 240kV (912L) Dome EM 4 to Cypress 2 CKT 11 240kV (945L) Janet 4 to East Calgary CKT 17 240kV Sarcee 4 to East Calgary CKT 16 240kV Nevis 4 to Cordell 4 240kV (9L20) Benalto 4 to Sarcee 4 CKT 28 240kV 6.2 Summary - Stability Analysis Dynamic analysis has been performed to evaluate the stability of the system before and after the addition of the Wild Rose plant. 36 contingencies were performed, including Category B and C events, for 2 existing system base cases and 4 wind added base cases. The wind-added base cases include heavy and light conditions, both before the addition of the SATR network upgrades (2012) and after (2013). A summary of the worst unstable contingencies is presented in Table 6-3. 6.2.1 Results and Observations Loss of the double circuit line (N-2) between Cypress and Ware Junction leaves the Empress area in a very weak condition, and depending on the status of the McNeil DC tie can result in load/generation imbalance in the area. This imbalance may be sufficient to cause instability. This condition is not eliminated by the addition of Wild Rose wind farm in 2012, but the generation/load balance does change depending on wind levels. It is expected that this problem will be reduced due to the strengthened ties into the Empress area planned with the Hanna Area upgrades. Until these upgrades are implemented, system operations will limit generation levels in the area to alleviate the potential for this condition. For the 2013 cases with existing generating units at full power, dynamic instability is still evident when ahigh level of existing generation is in service and either or both of the lines south through Anderson are interrupted. Additionally, poor damping is evident when the double-circuit line is lost between West Brook and Milo Junction . The Wild Rose plant does not improve this existing condition, and may be required to participate in existing OPPs dealing with this concern. 6.2.1.1 2012 (Pre-SATR) Discussion and Recommendations In 2012 the wind farm is connected radially into Cypress via a relatively long line, and low short circuit levels are evident at the Elkwater bus. Aside from the issues mentioned above and in Chapter 5.2, stability is maintained after several seconds, and post fault voltages are acceptable. Alberta Electric System Operator 479,693 72 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 6-3 Summary of unstable contingencies Base Case S1C2ES S1C2GGA S5C2GGA Contingenc y N-2 Expected Stable? (Summary) C17 X Unstable (loss of 240 ccts from Cypress to Jenner… no supply to Empress Area load) C18 X Unstable (same comment as C17) C17 X C18 X C17 X C18 X C5 X Unstable (Loss of Anderson to WB line) C8 X Unstable (Loss of Anderson to WJ line) C19 X Unstable (2 cct outage from WJ to Anderson) C20 X Unstable (2 cct outage from WJ to Anderson) C21 √ Poor damping - Oscillations last 15 seconds, 100001,2-CASTLE, 3,4,5-MACBRIDE, 6,7-SUMMERG, 8,9,11,12-KETTLES Tripped C5 X Unstable (Loss of Anderson to WB line) C8 X Unstable (Loss of Anderson to WJ line) C19 X Unstable (2 cct outage from WJ to Anderson) C21 √ Under damped - Oscillations last 15 seconds, 100001,2-CASTLE, 3,4,5-MACBRIDE, 6,7-SUMMERG, 8,9-KETTLES Tripped N-2 N-2 N-1 S8C2GGA N-2 N-1 S10C2GGA N-2 Comments Unstable - Loss of 2 ccts from Empress to WJ result in too much generation at Empress (use x-trip) Weak System: See comment C17, but system stays together with wind farm control oscillations. X-trip probably required for backup. Unstable - Loss of 2 ccts from Empress to WJ result in too much generation at Empress (use x-trip) Unstable - Loss of 2 ccts from Empress to WJ result in too much generation at Empress (use x-trip) Alberta Electric System Operator 479,693 73 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Table 6-4 Contingency description for unstable contingencies Contingency Reference # Elements Outage Fault Fault Location (line end) CAT B (N-1) C5 9L 933 - from Anderson to W.Brook 3LG Anderson 240kV Substation -801S C8 9L950 or 9L934 - from Ware Junction to Anderson 3LG Anderson 240kV Substation - 801S CAT C (N-2) C17 945L/951L - from Cypress to Jenner 3LG Cypress 240kV Substation - 562S C18 944L - from Jenner to Ware Junction 3LG Ware Jct 240kV Substation -132S C19 9L950/9L934 - from Ware Junction to Anderson 3LG Anderson 240kV Substation -801S C20 9L950/9L934 - from Ware Junction to Anderson 3LG Ware Junction 240kV Substation - 132S C21 923L/924L - from W. Brook to N.Lethbridge (Milo for 2013 cases) 3LG West Brooks 240kV Substation - 28S 6.3 Summary - Short Circuit Analysis Short Circuit Analysis has been performed for selected fault locations near the Wild Rose Wind Farm. All substation equipment should be checked during the project design to ensure that fault levels do not exceed equipment specifications. 6.4 Conclusions The study results showed that the connection of the 400 MW Wild Rose wind projects increase system overloads under both normal and Category B and Category C contingency conditions. In addition, current system stability issues associated with existing generation continue with the addition of the Project. The Category B overloads identified as being made worse or fully attributed to the Project will require incorporation of the Project in to existing Remedial Action Schemes (RAS) or the development of new RAS. The RAS should resolve the overloads in the interim, while future system developments planned for the area, including those approved as part of the SATR and Hanna Area, are expected to permanently address these issues. Certain Category B and C contingencies result in thermal and stability violations that will require that the system be managed via existing OPPs or new ones that will be required. System operating studies will be developed closer to the in-service date of the Project and any new OPPs required will be developed at that time. Alberta Electric System Operator 479,693 74 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 7.0 Responsibilities, Signature and Seal This Report was prepared by Electranix Corporation on behalf of NEC for the sole purpose of assisting the AESO with the preparation of the Need Information Filing associated with the interconnection requirements of the Wild Rose 1 and 2 wind projects. To prepare this report, Electranix required information that was provided by the AESO (particularly powerflow cases and assumptions) and Acciona (particularly custom dynamic models and powerflow assumptions). In addition, information pertaining to the proposed mitigation of constraints or criteria violations identified by Electranix was provided by the AESO. Electranix was responsible for conducting the system impact studies and preparing this report in reliance upon this information, and according to their professional judgement. While Electranix has no reason to believe that the information provided by the AESO, and on which this report is based, is inaccurate in any material respect, Electranix has not independently verified such information and cannot guarantee its accuracy or completeness. To the extent that actual future conditions or assumptions differ from the information provided to Electranix, the results will vary from those reported here. I hereby certify, as a Professional Engineer in the province of Alberta, that the information in this document was assembled under my direct personal charge. This report is not intended or represented to be suitable for re-use by the AESO or others without specific verification or adaptation by the Engineer. Signed and sealed, __________________________ Andrew Isaacs P.Eng. (Alberta) Date: October 25, 2010 _ Alberta Electric System Operator 479,693 75 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Appendices Appendix A: Appendix B: Appendix C: Appendix D: Single Line Diagrams Category C Powerflow Contingency Analysis PSSE Dynamic Invocations (DYRE records) Dynamic Traces Alberta Electric System Operator 479,693 76 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Appendix A: Single Line Diagrams Alberta Electric System Operator 479,693 77 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1ES_N0 - 2012 Summer Light Existing System 0MW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 78 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1ES_D7 - Nevis 240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) outage Overloaded branch Branch outage Alberta Electric System Operator 479,693 79 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2ES_N0 - 2012 Summer Light Existing System 150MW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 80 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2ES_D7 - Nevis 240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) outage Alberta Electric System Operator 479,693 81 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2ES_D18 - EmpressA7 to Cypress 1 138kV line overloading, Dome EM 4 to Cypress 2 CKT 11 240kV (945L) outage Alberta Electric System Operator 479,693 82 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2ES_D19 - EmpressA7 to Cypress 1 138kV line overloading, Dome EM 7 to Cypress 1 CKT 69 138kV outage Alberta Electric System Operator 479,693 83 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S3ES_N0 - 2012 Summer Light Existing System 150MW export to Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 84 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S3ES_D7 - Nevis 240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) outage. Alberta Electric System Operator 479,693 85 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4ES_N0 - 2012 Summer Peak Existing System 0MW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 86 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4ES_E7 - Ellersli to Argylle 240kV line overloading, Bellamy 4 to Argyll W CKT 04 240kV outage. Alberta Electric System Operator 479,693 87 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5ES_N0 - 2012 Summer Peak Existing System 0MW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 88 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5ES_E7- Ellersli to Argylle 240kV line overloading, Bellamy 4 to Argyll W CKT 04 240kV outage. Alberta Electric System Operator 479,693 89 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5ES_E15 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 7 to Cypress 1 CKT 69 138kV outage. Alberta Electric System Operator 479,693 90 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1GA_N0 - 2012 Summer Light Wild Rose 200 MW and 0MW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 91 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1GA_D7 - Nevis 240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) outage. Alberta Electric System Operator 479,693 92 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1GA_D18 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 4 to Cypress 2 CKT 11 240kV (945L) outage. Alberta Electric System Operator 479,693 93 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GA_N0 - 2012 Summer Light Wild Rose 200 MW and 150MW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 94 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GA_D4 - West Brook 7 to Bassano Tap 138kV, Queens Town to Bassano Tap 138kV line overloading, Red Deer to Nevis 240kV (912L) outage. Alberta Electric System Operator 479,693 95 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GA_D5 - West Brook 7 to Bassano Tap 138kV line overloading, Langdon 4 to West Brook 240kV (924L) outage. Alberta Electric System Operator 479,693 96 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GA_D7 - Nevis 240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) outage. Alberta Electric System Operator 479,693 97 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GA_D18 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 4 to Cypress 2 CKT 11 240kV (945L) outage. Alberta Electric System Operator 479,693 98 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S3GA_N0 - 2012 Summer Light Wild Rose 200MW and 150MW export to Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 99 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S3GA_D7 - Nevis 240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) outage. Alberta Electric System Operator 479,693 100 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1GGA_N0 - 2012 Summer Light Wild Rose 400MW and OMW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 101 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1GGA_D4 - West Brook 7 to Bassano Tap 138kV, Queens Town to Bassano Tap 138kV lines overloading, Red Deer to Nevis 240kV (912L) outage. Alberta Electric System Operator 479,693 102 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1GGA_D5 - West Brook 7 to Bassano Tap 138kV line overloading, Langdon 4 to West Brook 240kV (924L) outage. Alberta Electric System Operator 479,693 103 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1GGA_D7 - Nevis 240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) outage. Alberta Electric System Operator 479,693 104 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1GGA_D18 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 4 to Cypress 2 CKT 11 240kV (945L) outage. Alberta Electric System Operator 479,693 105 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GGA_N0 - 2012 Summer Light Wild Rose 400MW and 15OMW import from Saskatchewan N-0 conditions. Empress A7 to Cypress 1 138kV line overloading. Alberta Electric System Operator 479,693 106 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GGA_D1 - Red Deer to Nevis (912L), Suffield to MH (892L), Chappice Lake to Glenridge 138kV, Cypress to Glenridge overloading, Ware Junction to West Brook 4 240kV (931L) line outage. Alberta Electric System Operator 479,693 107 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GGA_D2 - Suffield 7 to Medicine Hat 7 (892L), Empress A7 to Cypress1 138kV lines overloading, Fincastle 7 to Taber CKT 10 138kV(610L) outage Alberta Electric System Operator 479,693 108 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GGA_D3 - Suffield 7 to Medicine Hat 7 (892L), Empress A7 to Cypress1 138kV lines overloading, Bulls Head 7 to Medicine Hat 7 CKT 80 138kV outage Alberta Electric System Operator 479,693 109 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GGA_D4 - West Brook 7 to Bassano Tap 138kV, Queens Town to Bassano Tap 138kV lines overloading, Red Deer to Nevis 240kV (912L) outage . Alberta Electric System Operator 479,693 110 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GGA_D5 - West Brook 7 to Bassano Tap 138kV, Queens Town to Bassano Tap 138kV, Red Deer to Nevis (912L) lines overloading, Langdon 4 to West Brook 240kV (924L) outage. (Note: Vulcan 7 to Steveley to Fort MA7 overloading is not within the Monitored area) Alberta Electric System Operator 479,693 111 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GGA_D7 - West Brook 7 to Bassano Tap 138kV, Queens Town to Bassano Tap 138kV, Nevis 240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) outage. Alberta Electric System Operator 479,693 112 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2GGA_D18 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 4 to Cypress 2 CKT 11 240kV (945L) outage. Alberta Electric System Operator 479,693 113 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S3GGA_N0 - 2012 Summer Light Wild Rose 400MW and 15OMW export to Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 114 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S3GGA_D7 - Nevis 240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) outage. Alberta Electric System Operator 479,693 115 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S3GGA_D4 - West Brook 7 to Bassano Tap 138kV line overloading, Red Deer to Nevis 240kV (912L) outage. Alberta Electric System Operator 479,693 116 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4GA_N0 - 2012 Summer Peak Wild Rose 200MW and OMW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 117 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4GA_E7 - Ellersli to Argylle 240kV line overloading, Bellamy 4 to Argyll W CKT 04 240kV outage. Alberta Electric System Operator 479,693 118 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GA_N0 - 2012 Summer Peak Wild Rose 200MW and 15OMW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 119 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GA_E5 - Chappice Lake to Glenridge 138kV, Cypress to Glenridge, Chappice Lake to Glenridge lines overloading, Ware Junction to West Brook 4 240kV (931L) line outage. Alberta Electric System Operator 479,693 120 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GA_E7 - Ellersli to Argylle 240kV line overloading, Bellamy 4 to Argyll W CKT 04 240kV outage. Alberta Electric System Operator 479,693 121 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GA_E14 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 4 to Cypress 2 CKT 11 240kV (945L) line outage. Alberta Electric System Operator 479,693 122 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GA_E15 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 7 to Cypress 1 CKT 69 138kV line outage. Alberta Electric System Operator 479,693 123 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GA_E16 - Empress A7 to Cypress 1 138kV line overloading, Chappice Lake 7 to Medicine Hat 7 CKT 60 138kV line outage. Alberta Electric System Operator 479,693 124 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GA_E17 - Empress A7 to Cypress 1 138kV line overloading, Chappice Lake to Glenridge CKT 58 138kV line outage. Alberta Electric System Operator 479,693 125 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GA_E18 - Empress A7 to Cypress 1 138kV line overloading, Cypress 1 to Glenridge CKT58 138kV line outage. Alberta Electric System Operator 479,693 126 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S6GA_N0 - 2012 Summer Peak Wild Rose 200MW and 15OMW export to Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 127 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S6GA_E7 - Ellersli to Argylle 240kV line overloading, Bellamy 4 to Argyll W CKT 04 240kV outage. Alberta Electric System Operator 479,693 128 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4GGA_N0 - 2012 Summer Peak Wild Rose 400MW and OMW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 129 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4GGA_E1 - West Brook 7 to Bassano Tap 138kV line overloading, Red Deer to Nevis 240kV (912L) line outage. Alberta Electric System Operator 479,693 130 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4GGA_E5 - Chappice Lake to Glenridge 138kV, Cypress to Glenridge, Chappice Lake to Medicine Hat 7 138kV lines overloading, Ware Junction to West Brook 4 240kV (931L) line outage. Alberta Electric System Operator 479,693 131 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4GGA_E7 - Ellersli to Argylle 240kV line overloading, Bellamy 4 to Argyll W CKT 04 240kV outage. Alberta Electric System Operator 479,693 132 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4GGA_E14 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 4 to Cypress 2 CKT 11 240kV (945L) line outage. Alberta Electric System Operator 479,693 133 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_N0 - 2012 Summer Peak Wild Rose 400MW and 15OMW import from Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 134 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_E1 - Chappice Lake to Glenridge 138kV, Cypress to Glenridge, Chappice Lake to Glenridge, West Brook 7 to Bassano Tap, Queens Town to Bassano Tap lines overloading, Red Deer to Nevis 240kV (912L) line outage. Alberta Electric System Operator 479,693 135 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_E2 - West Brook 7 to Bassano Tap, Queens Town to Bassano Tap lines overloading, Langdon 4 to West Brook 240kV (924L) line outage. Alberta Electric System Operator 479,693 136 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_E4 - West Brook 7 to Bassano Tap, Nevis240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) line outage. Alberta Electric System Operator 479,693 137 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_E5 - Chappice Lake to Glenridge 138kV, Cypress to Glenridge, Chappice Lake to Medicine Hat 7 138kV lines overloading, Ware Junction to West Brook 4 240kV (931L) line outage. Alberta Electric System Operator 479,693 138 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_E6 - Chappice Lake to Glenridge 138kV, Cypress to Glenridge, Chappice Lake to Medicine Hat 7 138kV lines overloading, Tilley 7 to West Brook 7 CKT 66 138kV line outage. Alberta Electric System Operator 479,693 139 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_E14 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 4 to Cypress 2 CKT 11 240kV (945L) line outage. Alberta Electric System Operator 479,693 140 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_E15 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 7 to Cypress 1 CKT 69 138kV line outage. Alberta Electric System Operator 479,693 141 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_E16 - Empress A7 to Cypress 1 138kV line overloading, Chappice Lake 7 to Medicine Hat 7 CKT 60 138kV line outage. Alberta Electric System Operator 479,693 142 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_E17 - Empress A7 to Cypress 1 138kV line overloading, Chappice Lake to Glenridge CKT 58 138kV line outage. Alberta Electric System Operator 479,693 143 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5GGA_E18 - Empress A7 to Cypress 1 138kV line overloading, Cypress 1 to Glenridge CKT58 138kV line outage. Alberta Electric System Operator 479,693 144 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S6GGA_N0 - 2012 Summer Peak Wild Rose 400MW and 15OMW export to Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 145 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S6GGA_E7 - Ellersli to Argylle 240kV line overloading, Bellamy 4 to Argyll W CKT 04 240kV outage. Alberta Electric System Operator 479,693 146 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S8GGA_N0 - 2013 Summer Light Wild Rose 400MW and OMW import from to Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 147 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S8GGA_C1 - Red Deer to Red Deer B 240kV/138kV transformer overloading, Gaetz 4 to Red Deer 4 CKT 14 240kV line outage. Alberta Electric System Operator 479,693 148 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S8GGA_C2 - Red Deer to Nevis 240kV (912L) line overloading, Langdon 4 to Milo Junction 240kV (924L) line outage. Alberta Electric System Operator 479,693 149 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S8GGA_C6 - Red Deer to Nevis 240kV (912L) line overloading, Ware Junction to West Brook 4 240kV (931L) line outage. Alberta Electric System Operator 479,693 150 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S8GGA_C5 - Nevis 240kV/138kV transformer, Nevis 4 to Cordell 4 240kV (9L20) line outage. Alberta Electric System Operator 479,693 151 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S9GGA_N0 - 2013 Summer Peak Wild Rose 400MW and OMW import from to Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 152 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S9GGA_C3 - Janet 4 to Janet 7 240kV/138kV transformers overloading, Janet 4 to East Calgary CKT 17 240kV line outage. Alberta Electric System Operator 479,693 153 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S9GGA_C4 - East Calgary Enmax2S7 240kV/138kV T1 transformer overloading, Sarcee 4 to East Calgary CKT 16 240kV line outage. Alberta Electric System Operator 479,693 154 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S10GGA_N0 - 2013 Summer Peak Wild Rose 400MW and 15OMW import from to Saskatchewan N-0 conditions. Alberta Electric System Operator 479,693 155 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S10GGA_C3- Janet 4 to Janet 7 240kV/138kV transformers overloading, Janet 4 to East Calgary CKT 17 240kV line outage. Alberta Electric System Operator 479,693 156 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S10GGA_C4 - East Calgary Enmax2S7 240kV/138kV T1 transformer overloading, Sarcee 4 to East Calgary CKT 16 240kV line outage. Alberta Electric System Operator 479,693 157 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S10GGA_C5 - Nevis 240kV/138kV transformer overloading, Nevis 4 to Cordell 4 240kV (9L20) Alberta Electric System Operator 479,693 158 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S10GGA_C15 - Janet 4 to East Calgary 17 line outage, Benalto 4 to Sarcee 4 CKT 28 240kV line outage. Alberta Electric System Operator 479,693 159 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S10GGA_C16 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 4 to Cypress 2 CKT 11 240kV (945L) line outage. Alberta Electric System Operator 479,693 160 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S10GGA_C17 - Empress A7 to Cypress 1 138kV line overloading, Battle River 79 to Cordell 4 CKT 79 240kV line outage. Alberta Electric System Operator 479,693 161 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S10GGA_C18 - Empress A7 to Cypress 1 138kV line overloading, Dome EM 7 to Cypress 1 CKT 69 138kV line outage. Alberta Electric System Operator 479,693 162 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S10GGA_C19 - Empress A7 to Cypress 1 138kV line overloading, Cypress 1 to Glenridge CKT58 138kV line outage. Alberta Electric System Operator 479,693 163 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Appendix B: Category C Powerflow Contingency Analysis Note: Overloading on Janet to Peigan (911L) and Landon SVC reported in most of Category C contingencies and not reported in these tables. S1C2ES - ( 2012 Summer Light case, 0 MW Wild Rose, 0 MW Import from Sask.) 944L - Jenner to Ware Junction 9L950/9L934 - Ware Junction to Anderson 923L/924L - W. Brook to N.Lethbridge 1034L/1035L - Bowmanton to W.Brook Both circuits lost between Bowmanton and Elkwater Line West towards Whitla/Lethbridge - 117% - N/A N/A N/A Fincastle 7 to Taber CKT 10 138kV(610L) Red Deer to Nevis 240kV (912L) Carsela 7 to Janet 7 CKT50 138kV Carsela 7 to Blackie 7 CKT51 138kV Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Dome EM 7 to EMPLIQTP CKT 60 138kV Suffield 7 to Tilley 7 CKT 00 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV EMPLIQ Tap to KSP Tap CKT 60 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer Not Converged Overloaded Line Not Converged 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 164 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2C2ES - ( 2012 Summer Light case, 0 MW Wild Rose, 150 MW Import from Sask.) 944L - Jenner to Ware Junction 9L950/9L934 - Ware Junction to Anderson 923L/924L - W. Brook to N.Lethbridge 1034L/1035L - Bowmanton to W.Brook Both circuits lost between Bowmanton and Elkwater Line West towards Whitla/Lethbridge - 121% 123% 113% - N/A N/A N/A Fincastle 7 to Taber CKT 10 138kV(610L) Red Deer to Nevis 240kV (912L) Carsela 7 to Janet 7 CKT50 138kV Carsela 7 to Blacki 7 CKT51 138kV Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Dome EM 7 to EMPLIQTP CKT 60 138kV Suffield 7 to Tilley 7 CKT 00 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV EMPLIQ Tap to KSP Tap CKT 60 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer Not Converged Overloaded Line Not Converged 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 165 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S3C2ES - ( 2012 Summer Light case, 0 MW Wild Rose, 150 MW export to Sask.) 944L - Jenner to Ware Junction 9L950/9L934 - Ware Junction to Anderson 923L/924L - W. Brook to N.Lethbridge 1034L/1035L - Bowmanton to W.Brook Both circuits lost between Bowmanton and Elkwater Line West towards Whitla/Lethbridge - 112% - N/A N/A N/A Fincastle 7 to Taber CKT 10 138kV(610L) Red Deer to Nevis 240kV (912L) Carsela 7 to Janet 7 CKT50 138kV Carsela 7 to Blacki 7 CKT51 138kV Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Dome EM 7 to EMPLIQTP CKT 60 138kV Suffield 7 to Tilley 7 CKT 00 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV EMPLIQ Tap to KSP Tap CKT 60 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer Not Converged Overloaded Line Not Converged 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 166 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4C2ES - ( 2012 Summer peak case, 0 MW Wild Rose, 0 MW export to Sask.) 944L - Jenner to Ware Junction 9L950/9L934 - Ware Junction to Anderson 923L/924L - W. Brook to N.Lethbridge 1034L/1035L - Bowmanton to W.Brook Both circuits lost between Bowmanton and Elkwater Line West towards Whitla/Lethbridge - - N/A N/A N/A Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CK 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV Nevis 240kV/138kV transformer Not Converged Overloaded Line Not Converged 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 167 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5C2ES - ( 2012 Summer peak, 0 MW Wild Rose, 150 MW import from Sask.) 944L - Jenner to Ware Junction 9L950/9L934 - Ware Junction to Anderson 923L/924L - W. Brook to N.Lethbridge 1034L/1035L - Bowmanton to W.Brook Both circuits lost between Bowmanton and Elkwater Line West towards Whitla/Lethbridge - 109% - N/A N/A N/A Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV Nevis 240kV/138kV transformer Not Converged Overloaded Line Not Converged 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 168 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S6C2ES - ( 2012 Summer peak case, 0 MW Wild Rose, 150 MW export to Sask.) 923L/924L - W. Brook to N.Lethbridge 1034L/1035L - Bowmanton to W.Brook Both circuits lost between Bowmanton and Elkwater Line West towards Whitla/Lethbridge - 109% - N/A N/A N/A 944L - Jenner to Ware Junction 9L950/9L934 - Ware Junction to Anderson Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Shuffle 7 to Medicine Hat 7 CKT 92 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV Nevis 240kV/138kV transformer Not Converged Overloaded Line Not Converged 945L/951L - Cypress to Jenner Contingency - Alberta Electric System Operator 479,693 169 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1C2GA - ( 2012 Summer Light case, 200 MW Wild Rose, 0 MW export to Sask.) 122% 131% 121% - Line West towards Whitla/Lethbridge - - N/A 923L/924L - W. Brook to N.Lethbridge - Both circuits lost between Bowmanton and Elkwater 9L950/9L934 - Ware Junction to Anderson - 1034L/1035L - Bowmanton to W.Brook 944L - Jenner to Ware Junction Fincastle 7 to Taber CKT 10 138kV(610L) Red Deer to Nevis 240kV (912L) Carsela 7 to Janet 7 CKT50 138kV Carsela 7 to Blacki 7 CKT51 138kV Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Dome EM 7 to EMPLIQTP CKT 60 138kV Suffield 7 to Tilley 7 CKT 00 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV EMPLIQ Tap to KSP Tap CKT 60 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer N/A Overloaded Line 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 170 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2C2GA - ( 2012 Summer Light case, 200 MW Wild Rose, 150 MW import from Sask.) 113% 127% 114% 155% 146% - Line West towards Whitla/Lethbridge - - N/A 923L/924L - W. Brook to N.Lethbridge - Both circuits lost between Bowmanton and Elkwater 9L950/9L934 - Ware Junction to Anderson 107% 106% 110% - 1034L/1035L - Bowmanton to W.Brook 944L - Jenner to Ware Junction Fincastle 7 to Taber CKT 10 138kV(610L) Red Deer to Nevis 240kV (912L) Carsela 7 to Janet 7 CKT50 138kV Carsela 7 to Blacki 7 CKT51 138kV Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Dome EM 7 to EMPLIQTP CKT 60 138kV Suffield 7 to Tilley 7 CKT 00 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV EMPLIQ Tap to KSP Tap CKT 60 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer N/A Overloaded Line 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 171 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S3C2GA - ( 2012 Summer Light case, 200 MW Wild Rose, 150 MW export to Sask.) 119% 112% 111% - 160% 153% 152% - - - - Line West towards Whitla/Lethbridge 118% - N/A - Both circuits lost between Bowmanton and Elkwater 108% - 1034L/1035L - Bowmanton to W.Brook 923L/924L - W. Brook to N.Lethbridge - N/A 9L950/9L934 - Ware Junction to Anderson Fincastle 7 to Taber CKT 10 138kV(610L) Red Deer to Nevis 240kV (912L) Carsela 7 to Janet 7 CKT50 138kV Carsela 7 to Blacki 7 CKT51 138kV Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Dome EM 7 to EMPLIQTP CKT 60 138kV Suffield 7 to Tilley 7 CKT 00 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV EMPLIQ Tap to KSP Tap CKT 60 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer 944L - Jenner to Ware Junction Overloaded Line 945L/951L - Cypress to Jenner Contingency - Alberta Electric System Operator 479,693 172 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S1C2GGA - ( 2012 Summer Light case, 400 MW Wild Rose, 0 MW export to Sask.) 114% 121% 121% - - - 153% 105% - Line West towards Whitla/Lethbridge 117% 105% 113% 128% 119% 163% N/A - Both circuits lost between Bowmanton and Elkwater 106% - 1034L/1035L - Bowmanton to W.Brook 923L/924L - W. Brook to N.Lethbridge 122% 117% 128% - N/A 9L950/9L934 - Ware Junction to Anderson Fincastle 7 to Taber CKT 10 138kV(610L) Red Deer to Nevis 240kV (912L) Carsela 7 to Janet 7 CKT50 138kV Carsela 7 to Blacki 7 CKT51 138kV Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Dome EM 7 to EMPLIQTP CKT 60 138kV Suffield 7 to Tilley 7 CKT 00 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV EMPLIQ Tap to KSP Tap CKT 60 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer 944L - Jenner to Ware Junction Overloaded Line 945L/951L - Cypress to Jenner Contingency - Alberta Electric System Operator 479,693 173 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S2C2GGA - ( 2012 Summer Light, 400 MW Wild Rose, 150 MW import from Sask.) - 130% 113% 120% 134% 130% - 157% 143% 139% 121% 156% 136% 187% 168% - - - - - - 188% - 221% 228% 229% 141% - 172% 179% 179% 122% - - 178% 108% 113% - Line West towards Whitla/Lethbridge N/A Both circuits lost between Bowmanton and Elkwater 1034L/1035L - Bowmanton to W.Brook 126% 114% - N/A Fincastle 7 to Taber CKT 10 138kV(610L) Red Deer to Nevis 240kV (912L) Carsela 7 to Janet 7 CKT50 138kV Carsela 7 to Blacki 7 CKT51 138kV Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Dome EM 7 to EMPLIQTP CKT 60 138kV Suffield 7 to Tilley 7 CKT 00 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV EMPLIQ Tap to KSP Tap CKT 60 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer 923L/924L - W. Brook to N.Lethbridge Overloaded Line 944L - Jenner to Ware Junction 9L950/9L934 - Ware Junction to Anderson 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 174 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ 3C2GGA - ( 2012 Summer Light case, 400 MW Wild Rose, 150 MW export to Sask.) - 104% 123% 103% - - - - - - - - - 139% - - - - 129% - - N/A N/A Line West towards Whitla/Lethbridge - Both circuits lost between Bowmanton and Elkwater 923L/924L - W. Brook to N.Lethbridge - 1034L/1035L - Bowmanton to W.Brook 9L950/9L934 - Ware Junction to Anderson Fincastle 7 to Taber CKT 10 138kV(610L) Red Deer to Nevis 240kV (912L) Carsela 7 to Janet 7 CKT50 138kV Carsela 7 to Blacki 7 CKT51 138kV Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Dome EM 7 to EMPLIQTP CKT 60 138kV Suffield 7 to Tilley 7 CKT 00 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV EMPLIQ Tap to KSP Tap CKT 60 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer 944L - Jenner to Ware Junction Overloaded Line 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 175 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4C2GA - ( 2012 Summer peak case, 200 MW Wild Rose, 0 MW export to Sask.) 117% 107% - Line West towards Whitla/Lethbridge - - N/A 923L/924L - W. Brook to N.Lethbridge - Both circuits lost between Bowmanton and Elkwater 9L950/9L934 - Ware Junction to Anderson - 1034L/1035L - Bowmanton to W.Brook 944L - Jenner to Ware Junction Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV Nevis 240kV/138kV transformer N/A Overloaded Line 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 176 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5C2GA - (2012 Summer peak case, 200 MW Wild Rose, 150 MW import from Sask.) 141% 131% - Line West towards Whitla/Lethbridge - - N/A 923L/924L - W. Brook to N.Lethbridge - Both circuits lost between Bowmanton and Elkwater 9L950/9L934 - Ware Junction to Anderson - 1034L/1035L - Bowmanton to W.Brook 944L - Jenner to Ware Junction Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV Nevis 240kV/138kV transformer N/A Overloaded Line 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 177 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S6C2GA - (2012 Summer peak case, 200 MW Wild Rose, 150 MW export to Sask.) Both circuits lost between Bowmanton and Elkwater Line West towards Whitla/Lethbridge - N/A 923L/924L - W. Brook to N.Lethbridge - 1034L/1035L - Bowmanton to W.Brook 9L950/9L934 - Ware Junction to Anderson - N/A 944L - Jenner to Ware Junction Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV Nevis 240kV/138kV transformer Not Converged Overloaded Line Not Converged 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 178 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S4C2GGA - (2012 Summer peak case, 400 MW Wild Rose, 0 MW export to Sask.) 136% 144% 145% - 108% 108% - - 138% - - Line West towards Whitla/Lethbridge 147% N/A - Both circuits lost between Bowmanton and Elkwater - 1034L/1035L - Bowmanton to W.Brook 923L/924L - W. Brook to N.Lethbridge 105% 105% - N/A 9L950/9L934 - Ware Junction to Anderson Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV Nevis 240kV/138kV transformer 944L - Jenner to Ware Junction Overloaded Line 945L/951L - Cypress to Jenner Contingency - Alberta Electric System Operator 479,693 179 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S5C2GGA - (2012 Summer peak, 400 MW Wild Rose, 150 MW import from Sask.) Line West towards Whitla/Lethbridge - N/A 104% 111% 171% 161% - Both circuits lost between Bowmanton and Elkwater 923L/924L - W. Brook to N.Lethbridge - 1034L/1035L - Bowmanton to W.Brook 9L950/9L934 - Ware Junction to Anderson 109% 199% 207% 207% - N/A 944L - Jenner to Ware Junction Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV Nevis 240kV/138kV transformer 945L/951L - Cypress to Jenner Overloaded Line Not Converged Contingency Alberta Electric System Operator 479,693 180 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S6C2GGA - (2012 Summer peak, 400 MW Wild Rose, 150 MW export to Sask.) - Line West towards Whitla/Lethbridge 124% 114% - - N/A 923L/924L - W. Brook to N.Lethbridge - Both circuits lost between Bowmanton and Elkwater 9L950/9L934 - Ware Junction to Anderson - 1034L/1035L - Bowmanton to W.Brook 944L - Jenner to Ware Junction Blackie 7 Vulcan 7 CKT 61 138kV Gleiche 7 to Queenstown CKT 76 138kV Empress 7 to Dome Empress 7 CKT 97 138kV Empress 7 to Cypress 1 CKT 68 138kV Suffield 7 to Medicine Hat 7 CKT 92 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Bassano Tap CKT 53 138kV Chappice Lake to Medicine Hat 7 CKT 60 138kV Chappice Lake to Glenridge CKT 58 138kV Queenstown to Bassano Tap CKT 53 138kV Cypress 1 to Glenridge CKT 58 138kV Nevis 240kV/138kV transformer N/A Overloaded Line 945L/951L - Cypress to Jenner Contingency Alberta Electric System Operator 479,693 181 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S8C2GGA - ( 2013 Summer Light, 400 MW Wild Rose, 0 MW Import from Sask.) Overloaded Line 945L/951L - Cypress to Jenner 944L - Jenner to Ware Junction 9L950/9L934 - Ware Junction to Anderson 923L/924L - W. Brook to N.Lethbridge 1034L/1035L - Bowmanton to W.Brook Both circuits lost between Bowmanton and Elkwater Line West towards Whitla/Lethbridge Contingency Red Deer to Red Deer B 240kV/138kV Transformer Red Deer to Nevis Janet 4 to Janet 7 240kV/138kV transformer East Calgary to Enmax Transformer 240kV/138kV Taber 7 to Vauxhal 7 CKT 63 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Ench Tap CKT 63 138kV Cordell 7 to Chin chute CKT 72 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer - - 113% - 142% 107% 128% 143% 119% 116% - - - Alberta Electric System Operator 479,693 182 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S9C2GGA - (2013 Summer peak, 400 MW Wild Rose, 0 MW import from Sask.) Overloaded Line 945L/951L - Cypress to Jenner 944L - Jenner to Ware Junction 9L950/9L934 - Ware Junction to Anderson 923L/924L - W. Brook to N.Lethbridge 1034L/1035L - Bowmanton to W.Brook Both circuits lost between Bowmanton and Elkwater Line West towards Whitla/Lethbridge Contingency Red Deer to Red Deer B 240kV/138kV Transformer Red Deer to Nevis Janet 4 to Janet 7 240kV/138kV transformer East Calgary to Enmax Transformer 240kV/138kV Taber 7 to Vauxhall 7 CKT 63 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Ench Tap CKT 63 138kV Cordell 7 to Chin chute CKT 72 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer - - - - - - - Alberta Electric System Operator 479,693 183 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ S10C2GGA - (2013 Summer peak, 400 MW Wild Rose, 150 MW import from Sask.) Overloaded Line 945L/951L - Cypress to Jenner 944L - Jenner to Ware Junction 9L950/9L934 - Ware Junction to Anderson 923L/924L - W. Brook to N.Lethbridge 1034L/1035L - Bowmanton to W.Brook Both circuits lost between Bowmanton and Elkwater Line West towards Whitla/Lethbridge Contingency Red Deer to Red Deer B 240kV/138kV Transformer Red Deer to Nevis Janet 4 to Janet 7 240kV/138kV transformer East Calgary to Enmax Transformer 240kV/138kV Taber 7 to Vauxhall 7 CKT 63 138kV Taber 7 to Chin chute CKT 72 138kV West Brook 7 to Ench Tap CKT 63 138kV Cordell 7 to Chin chute CKT 72 138kV Nevis 4 to Cordell 4 CKT 20 240kV Nevis 240kV/138kV transformer - - - 115% 115% 108% 111% 124% - - - - Alberta Electric System Operator 479,693 184 25/10/2010 Wild Rose Wind Farm – Interconnection Proposal Technical Analysis ______________________________________________________________________ Appendix C: Acciona DYR model invocation The dynamic model invocation for the Acciona wind farm used in the dynamic analysis is as follows. Note that these values differ from the recommended values in the Acciona documentation. Please refer to Acciona documentation for a full description of each dynamic record: 1601 'USRMDL' 1 'A1530X ' 0 1500 15.00 63.00 57.00 1.15 1.20 5.00 0.80 0.85 0.50 15.00 210.00 0.50 0.90 0.20 0.90 1.00 0.50 3.00 3000.00 500.00/ 2101 'USRMDL' 1 'A1530X ' 0 1500 15.00 63.00 57.00 1.15 1.20 5.00 0.80 0.85 0.50 15.00 210.00 0.50 0.90 0.20 0.90 1.00 0.50 3.00 3000.00 500.00/ 1602 'USRMDL' 1 'A1530X ' 0 1500 15.00 63.00 57.00 1.15 1.20 5.00 0.80 0.85 0.50 15.00 210.00 0.50 0.90 0.20 0.90 1.00 0.50 3.00 3000.00 500.00/ 2102 'USRMDL' 1 'A1530X ' 0 1500 15.00 63.00 57.00 1.15 1.20 5.00 0.80 0.85 0.50 15.00 210.00 0.50 0.90 0.20 0.90 1.00 0.50 3.00 3000.00 500.00/ 0 'USRMDL' 0 'AWTVRW' 8 0 19 335 0 4 1 1 5.00 0.10 1.00 0.90 0.90 25.00 1 5.00 0.10 1.00 0.90 0.90 25.00 1 1 2 2 32 0 2 2 32 0 2 0 2 5.00 0.10 2.75 0.40 1.00 500.00 1 5.00 0.10 1.00 0.90 0.90 25.00 2 0 5.00 0.10 2.75 0.40 1.00 500.00 5.00 0.10 1.00 0.90 0.90 25.00 6 32 5.00 0.10 2.75 0.40 1.00 500.00 1 1 2 2 32 5.00 0.10 2.75 0.40 1.00 500.00 3 1601 '1 ' 2101 '1 ' 1602 '1 ' 2102 '1 ' 0 '1 ' 0 '1 ' 0 '1 ' 0 '1 ' 0.5000 0.4000 0.0100 0.1000 0.3973 -0.3973/ Alberta Electric System Operator 479,693 185 25/10/2010