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POWER SYSTEMS CONSULTING

SYSTEM IMPACT STUDY FOR E001

FINAL DRAFT REPORT

REPORT NO.: 2013-E11415-R1

Issued On: September 12, 2013

Prepared for:Midcontinent Independent System Operator, Inc.

Prepared by:ABB Inc.Power Systems Consulting

940 Main Campus Drive, Suite 300Raleigh, NC 27606

12 Cornell RoadLatham, NY 12110

Legal NoticeThis document, prepared by ABB Inc. (ABB), is an account of work sponsored by MidcontinentIndependent System Operator, Inc. (MISO). Neither MISO nor ABB nor any person or personsacting on behalf of either party: (i) makes any warranty or representation, expressed or implied,with respect to the use of any information contained in this report, or that the use of anyinformation, apparatus, method, or process disclosed in this report may not infringe privatelyowned rights, or (ii) assumes any liabilities with respect to the use of or for damages resultingfrom the use of any information, apparatus, method, or process disclosed in this document.

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ABB Inc. – Power Systems Consulting Technical Report

MISO Report No. 2013-E11415-R1

System Impact Study for E001 September 12, 2013# Pages

29

Author(s): Reviewed by: Approved by:J. Jaeger S. Pillutla W. Wong

Executive Summary

MISO has requested ABB Power Systems Consulting perform a short-circuit and stability studyfor Project E001, which is an interconnection request for a proposed 200 MW wind farm in theEntergy service territory. The proposed project has requested interconnection at the Moon Lake230 kV substation.

The objective of this study is to determine if the interconnection of E001 would result in adverseshort-circuit or stability impacts on the Entergy system.

A summary of the study results is presented below.

Short-Circuit AnalysisShort-circuit analysis was performed using ASPEN models provided by Entergy. The focus ofthis analysis is to evaluate the impact of the proposed E001 project on fault duties atsubstations in the electrical vicinity of the proposed wind farm. Breaker fault duties werecomputed based on simulation of three-phase and single-line-to-ground faults. Entergy's short-circuit under-rated breaker rating methodology was used to identify impacted breakers.Comparison of the post-project fault duties against interrupting capabilities of existing breakersat substations in the local vicinity indicates that there is adequate interrupting capabilityfollowing the addition of the proposed wind farm.

Stability AnalysisStability analysis was performed on a 2017 Summer Peak case provided by Entergy. Fifteen(15) three-phase normally cleared and six (6) three-phase stuck-breaker faults were simulatedto determine the impact of E001 on the stability and transient voltage recovery of the localEntergy System.

One (1) three-phase stuck-breaker fault at the Batesville 230 kV bus was found to be unstable.Further investigation on a pre-project case (without E001) showed similar results. Hence, it wasconcluded that the instability is not attributable to E001. The system was stable following allother simulated normally-cleared three-phase faults and three-phase stuck-breaker faults.

Also, transient voltage criteria violations were observed for two (2) other three-phase stuck-breaker faults in the pre- and post-project cases. The faults with voltage criteria violations werefor faults at the Moon Lake 230 kV bus where the Moon Lake – Crossroads 230 kV branch is

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tripped as backup protection following a three-phase stuck-breaker fault. However, it has beendemonstrated that the violations exist prior to the addition of the E001 project, and that theimpact of E001 on the transient voltage violations following these faults is marginal.

Three-phase stuck breaker faults that exhibited stability or transient voltage violations, asdescribed in the preceding paragraphs, were re-simulated as corresponding single-line-to-ground (SLG) stuck-breaker faults. Results show no stability and transient voltage criteriaviolations for these faults.

The proposed project (E001) complies with FERC Order 661-A on low voltage ride through forwind farms. Results show that the proposed wind farm does not trip off-line by voltage relayactuation for local faults at the POI.

Based on the results of the above study, it can be concluded that the proposed E001 wind farmdoes not adversely impact the short-circuit or stability performance of the Entergy System.

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TABLE OF CONTENTS

1 INTRODUCTION .............................................................................. 1

2.1 PROJECT DESCRIPTION ..........................................................................2

2 SHORT-CIRCUIT ANALYSIS ........................................................... 3

2.2 METHODOLOGY AND CRITERIA .......................................................................3

2.3 MODELS .......................................................................................................3

2.4 SHORT-CIRCUIT ANALYSIS.............................................................................3

3 STABILITY ANALYSIS ..................................................................... 4

3.1 STABILITY ANALYSIS ASSUMPTIONS, METHODOLOGY, AND

CRITERIA 4

3.2 STUDY MODEL DEVELOPMENT ...............................................................5

3.2.1 Powerflow Case ..........................................................................................53.2.2 Stability Database .......................................................................................5

3.3 TRANSIENT STABILITY RESULTS AND ANALYSIS .................................8

3.3.1 Fault Definitions and Procedures.................................................................8

3.3.2 Stability Results .........................................................................................16

3.4 Low Voltage Ride Through ........................................................................24

4 CONCLUSIONS ............................................................................. 28

5 REFERENCED DOCUMENTS ....................................................... 29

APPENDIX A Data Provided by Customer ........................................................... 30

APPENDIX B PSS/E Dynamics Data ................................................................... 33

APPENDIX C Plots for Stability Simulations ......................................................... 36

APPENDIX D Short-Circuit Results ...................................................................... 39

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1 INTRODUCTIONMISO has requested ABB Power Systems Consulting perform a short-circuit and stability studyfor Project E001, which is an interconnection request for a proposed 200 MW wind farm in theEntergy service territory. The proposed project has requested interconnection at the Moon Lake230kV substation.

The objective of this study is to determine if the interconnection of E001 would result in anyadverse short-circuit or stability impacts on the Entergy system.

Figure 1.1 shows the geographic location the Moon lake 230kV substation, the proposed point-of-interconnection (POI) for the E001 project.

Figure 1.1: Point of Interconnection for E001

Moon Lake 230kVPOI for E001

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2.1 PROJECT DESCRIPTIONThe proposed E001 project will be located in the Entergy service territory. Power will begenerated from 87 Siemens 2.3 MW wind turbines generators. The following list summarizesthe major project parameters:

Point of Interconnection: Moon Lake 230kV substation

General:Wind Farm Gross MW: 200 MWNumber of Turbines: 87

Wind Turbine Generator:Manufacturer: SiemensModel: SWT2.3-VS 120MVA: 2.3 MVAType: 4, Full Converter InterfaceRated Terminal Voltage: 690 VFrequency: 60 HzPower Factor: 0.9 lagging – 0.9 leading

Generator Step-up Transformer (GSU):Capacity: 2.6 MVAHigh voltage: 34.5 kVLow voltage: 0.69 kVZ: 5.7% on 2.6 MVA base, X/R = 7.1

Collector System Equivalent Impedance:System Voltage: 34.5 kVR: 0.1622 pu on 100 MVA baseX: 0.2991 pu on 100 MVA baseB: 0.09572 pu on 100 MVA base

Substation Transformer:Capacity: 130/165/210 MVAHigh Voltage: 230 kVLow Voltage: 34.5 kVZ: 10.049% on 130 MVA base, X/R = 63

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2 SHORT-CIRCUIT ANALYSIS2.2 METHODOLOGY AND CRITERIAThe purpose of short-circuit analysis is to determine fault current levels at the point ofinterconnection, both before and after the addition of the proposed E001 project. Three-phaseand single-line-to-ground faults were simulated at the point of interconnection and at nearbysubstations to determine the impact of the proposed project on fault duties and to identifyoverdutied breakers, if any, as a result of fault current contributions from the proposed project.

2.3 MODELSEntergy provided two (2) pre-project ASPENTM models for the short-circuit analysis. It isunderstood that these models includes all generators interconnected to the Entergy system andinterconnected to an adjacent system and having an impact on this interconnection request,IPPs with signed IAs and approved future projects in the Entergy transmission system.

1. ENT_Plan.olr: Pre-project case without priors.

2. ENT_Plan With PID 247, 289 & 291.olr: Pre-project case with prior-queued projects: PID-247, PID-289 and PID-291.

The proposed E001 project was added to the above models in order to create thecorresponding post-project models. Two models were developed, one without priors and onewith priors (PID-247, PID-289 and PID-291).

2.4 SHORT-CIRCUIT ANALYSISShort-circuit analysis was performed using the ASPENTM software. Three-phase and single-line-to-ground faults were simulated on the above-mentioned models. Pre- and post-project faultduties were tabulated and compared against interrupting capabilities of breakers at nearbysubstations. Entergy's short-circuit under-rated breaker rating methodology was used to assessthe impact of the proposed wind farm on breaker fault duties.

Results of the short-circuit analysis are shown in Appendix D. Comparison of the post-projectfault duties against interrupting capabilities of existing breakers at substations in the localvicinity (Moon Lake 230 kV, Ritchie SES 230 kV, Tunica 115/230 kV, Batesville 230 kV, MEP-Clarksdale 230 kV) indicates that there is adequate interrupting capability following the additionof the proposed project.

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3 STABILITY ANALYSIS3.1 STABILITY ANALYSIS ASSUMPTIONS, METHODOLOGY, AND CRITERIAStability analysis was performed using Siemens-PTI’s PSS/ETM dynamics program V30.3.3.Three-phase faults with normal clearing and with breaker failures were simulated. It is assumedthat all 500kV breakers are Independent Pole Operated (IPO) and that the three phases of thebreaker operate independently. Thus for faults involving a 500 kV breaker failure only a singlephase fails to open, at which time the fault becomes single phase only.

Study criteria are based upon Section 7.8 of “Entergy Transmission Local Planning Criteria” [1].The exact criteria specified in the document are shown below for reference:

o Generator Instability:· If the generator rotor angle deviation with respect to a “distant” generator is more

than 180 degrees, the generator will slip poles. This condition is unacceptable asit imparts a big shock to the generator shaft and may reduce its life span. Anydeviation of rotor angle beyond 180 degrees is considered instability of thegenerator. It needs to be evaluated whether the instability is limited to a specificgenerator or sets of generators or an entire region becomes unstable.

o Voltage Dip:· 3-phase fault or single-line-ground fault with normal clearing resulting in the loss

of a single component (generator, transmission circuit or transformer) or a loss ofa single component without fault:§ Not to exceed 20% for more than 20 cycles at any bus§ Not to exceed 25% at any load bus§ Not to exceed 30% at any non-load bus

· 3-phase faults with normal clearing resulting in the loss of two or morecomponents (generator, transmission circuit or transformer), and SLG fault withdelayed clearing resulting in the loss of one or more components:§ Not to exceed 20% for more than 40 cycles at any bus§ Not to exceed 30% at any bus

· The duration of the transient voltage dip excludes the duration of the fault. Thetransient voltage dip criteria may not be applied to three-phase faults followed bystuck breaker conditions unless the determined impact is extremely widespread.

For each fault, the system is monitored for transient instability, voltage dip magnitude andduration, and rotor angle damping.

Voltage dip monitoring is initiated two cycles following fault clearing (i.e., voltage dip criteria isnot monitored for the duration of the fault). For the purposes of determining the voltage limitsduring three-phase and single-line-ground faults with normal clearing, a load bus is defined asany bus with one or more directly connected loads in the PSS/E case. Conversely, any buswithout a directly connected load will be defined as a non-load bus.

As there are no specific voltage dip criteria for three-phase stuck-breaker faults, the transientvoltage response of these faults were compared against the most stringent voltage dip criteriawhere voltage dip is not to exceed more than 20% of the pre-fault voltage for more than 20cycles at any bus, not to exceed 25% at any load bus, and not to exceed 30% at any non-loadbus. If the most stringent voltage criterion was not satisfied, then the post-fault transient

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voltages were compared against the less stringent criteria where bus voltage dip is not toexceed 20% for more than 40 cycles at any bus and not to exceed 30% at any bus.

3.2 STUDY MODEL DEVELOPMENTThe E001 Wind farm is composed of 87 wind turbines, each with a rating of 2.3 MW. Eachturbine is connected to a 0.69/34.5kV padmount step-up transformer. The 87 wind turbines areconnected to a wind farm collector network, which is then connected to the Moon Lake 230kVbus through a single 34.5/230 kV station transformer and a 230 kV transmission line.

For modeling purposes, the 87 wind turbines were lumped into a single generating unit with agross power output of 200 MW. The voltage at the wind turbine terminal is 690 V and is steppedup to 34.5 kV through generator step-up transformer, which is connected to the point ofinterconnection of E001 via 34.5/230 kV station transformer and a 230 kV transmission line.

Based on the provided data, the wind machine is capable of supplying/drawing reactive powerto/from the grid thus contributing to grid voltage support. The WTG reactive power capabilitycorresponds to a power factor range from 0.9 lagging to 0.9 leading.

Data for the proposed E001 project is included in APPENDIX A as provided by MISO and inAPPENDIX B in PSS/E v30.3 format.

The study model consists of a power flow case and a dynamics database, developed as follows:

3.2.1 Powerflow CaseA powerflow case “EN17S12_U2_CP_final_V30_unconv.sav” representing 2017 Summer Peakconditions was provided by Entergy.

The post-project powerflow case was provided by Entergy, and included E001 Wind Farmmodel interconnected at the Moon Lake 230 kV substation.

To create a pre-project case without E001, the E001 generator bus, 34.5 kV collector systembuses, and 230 kV interconnection buses were disconnected (PSS/E bus numbers 337118,337117, 337109, & 337108). Figure 3.1 and Figure 3.2 show the PSS/E one-line diagrams forthe local area without and with the E001 project, respectively.

3.2.2 Stability DatabasePSS/E basecase stability database files were provided by Entergy. Specifically, the filesprovided included red16S_newnum.dyr and drift.snp. These files included stability data andmodels for E001.

The E001 wind farm is modeled with all 87 wind turbines lumped into a single generator modelin PSS/E using a generic type 4 wind turbine model. The generator/converter model used wasW4GUR2 and the control model was W4EUR2, with parameters set for this specific Siemenswind turbine being used, as detailed in APPENDIX B.

The voltage and frequency ride through capability of the wind farm is modeled by a series ofunder/over voltage relays using the VTGDCA model and under/over frequency relays using theFRQDCA model. The details of these models are presented in APPENDIX B.

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Figure 3.1: 2017 Summer Peak Flows and Voltages without E001

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Figure 3.2: 2017 Summer Peak Flows and Voltages with E001

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3.3 TRANSIENT STABILITY RESULTS AND ANALYSIS

3.3.1 Fault Definitions and ProceduresStability simulations were run to examine the transient behavior of the E001 generation and itsimpact on the Entergy system. Stability analysis was performed using the following procedure.First, three-phase faults with normal clearing were simulated. Next, three-phase stuck-breakerfaults were simulated. If the stability and/or transient voltage criteria were not met for a givenfault then a single-line-to-ground (SLG) fault followed by a breaker-failure was studied.

The fault clearing times used for the simulations are given in Table 3.1.

Table 3.1: Fault Clearing Times

Faulted bus kV level Normal Clearing Delayed Clearing115 6 cycles 6+10 cycles230 6 cycles 6+10 cycles500 5 cycles 5+9 cycles

All line trips are assumed to be permanent (i.e., no high speed re-closure).

Table 3.2 and Table 3.3 list the fault cases that were simulated in this study for three-phasenormal clearing and three-phase stuck breaker faults, respectively. Fifteen (15) three-phasenormally cleared and six (6) three-phase stuck-breaker faults were simulated. Figure 3.3through Figure 3.7 show the breaker layout diagrams for substations where faults weresimulated.

For all cases analyzed, the initial disturbance was applied at t = 0.1 seconds.

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Table 3.2 List of faults simulated for stability analysis (3-phase faults with normal clearing)Fault # Faulted Line Type Clearing

Time (Cy) Primary Breakers Tripped Facilities

Fault 1 Moon Lake - Ritchie 230kV 3 PH 6 Moon Lake 230kV: J8762, J8766Ritchie 230kV: B4788

Moon Lake - Ritchie 230kV

Fault 2 Moon Lake - Batesville 230kV 3 PH 6 Moon Lake 230kV: J8770, JXXXXBatesville 230kV: J4408

Moon Lake - Batesville 230kV

Fault 3 Moon Lake - Crossroads 230kV 3 PH 6 Moon Lake 230kV: JXXXX, J8762Crossroads 230kV: 2230_2

Moon Lake - Crossroads 230kV

Fault 4 Crossroads - Clarksdale Transfm. 3 PH 6 Crossroads 230kV: 2230_5Clarksdale 115kV: 3115_2

Crossroads - Clarksdale Transfm.

Fault 5 Ritchie - Tunica 230kV 3 PH 6 Ritchie 230kV: B5144Tunica 230kV: J2716

Ritchie - Tunica 230kV

Fault 6 Ritchie - Aubrey 230kV 3 PH 6 Ritchie 230kV: B8044Brinkley 230kV: B7600

Ritchie - Aubrey 230kVAubrey - Brinkley E. 230kV

Fault 7 Ritchie - Stuttgart Ricuskey 230kV 3 PH 6 Ritchie 230kV: B4744Stuttgart Ricuskey 230kV: B8410, B8414

Ritchie - Stuttgart Ricuskey 230kV

Fault 8 Ritchie 230kV Bus #2 3 PH 6 Ritchie 230kV: 4430, 4788, 8044, 9722 Ritchie - Moon Lake 230kVRitchie Gen #2Ritchie - Aubrey 230kVAubrey - Brinkley E. 230kV

Fault 9 Ritchie 230/115kV Transfm. 3 PH 6 Ritchie 230 kV: B4401Ritchie 115 kV: B4402

Ritchie 230/115kV Transfm.

Fault 10 Batesville - LS Power 230kV 3 PH 6 Batesville 230kV: J4432LS Power 230kV: 161_13, 161_9

Batesville - LS Power 230kV

Fault 11 Batesville - Enid 230kV 3 PH 6 Batesville 230kV: J4404Tillatoba 230kV: J2524

Batesville - Enid 230kVEnid - N. Oakland 230kVN. Oakland - Tillatoba 230kV

Fault 12 Batesville 230kV Bus 3 PH 6 Batesville 230kV: J4404, J4408, J4410, J4432 Batesville - Moon Lake 230kVBatesville - LS Power 230kVBatesville 230/115kV Transfm.Batesville - Enid 230kVEnid - N. Oakland 230kVN. Oakland - Tillatoba 230kV

Fault 13 Tunica - Robinsonville 230kV 3 PH 6 Tunica 230kV: J5408Twinkletown 230kV: J7320

Tunica - Robinsonville 230kVRobinsonville -Twinkletown 230kV

Fault 14 Freeport - Birminham Steel 500kV 3 PH 5 Freeport 500kV: N/ABirminham Steel 500kV: N/A

Freeport - Birminham Steel 500kV

Fault 15 Freeport - Cordova 500kV 3 PH 5 Freeport 500kV: N/ACordova 500kV: N/A

Freeport - Cordova 500kV

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Table 3.3 List of faults simulated for stability analysis (3PH faults with stuck breaker)

Fault # Faulted Line TypeTotal Fault Clearing

Time (Cycles) Primary Breakers Stuck Breaker Secondary Breakers Tripped FacilitiesPrimary Backup

Fault 1A Moon Lake - Ritchie 230kV 3PH-3PH

6 16 Moon Lake 230kV: J8766Ritchie 230kV: B4788

Moon Lake 230kV: J8762 Moon Lake 230kV: JXXXXCrossroads 230kV: 2230_2

Moon Lake - Ritchie 230kV (6 cy)Moon Lake - Crossroads 230kV (16 cy)

Fault 2A Moon Lake - Batesville 230kV 3PH-3PH

6 16 Moon Lake 230kV: J8770Batesville 230kV: J4408

Moon Lake 230kV: JXXXX Moon Lake 230kV: J8762Crossroads 230 kV: 2230_2

Moon Lake - Batesville 230kV (6 cy)Moon Lake - Crossroads 230kV (16 cy)

Fault 8A Ritchie 230kV Bus #2 3PH-3PH

6 16 Ritchie 230kV: 4788, 8044,9722

Ritchie 230kV: 4430 Ritchie 230kV: B4744, B5144,B9721, B4401

Ritchie - Moon Lake 230kV (6 cy)Ritchie - Aubrey 230kV (6 cy)Aubrey - Brinkley E. 230kV (6 cy)Ritchie Gen #2 (6 cy)Ritchie - Stuttgart Ricuskey 230kV (16 cy)Ritchie - Tunica 230kV (16 cy)Ritchie 230/115kV Transfm. (16 cy)

Fault 11A Batesville - Enid 230kV 3PH-3PH

6 16 Tillatoba 230kV: J2524 Batesville 230kV: J4404 Batesville 230kV: J4408,J4410, J4432

Batesville - Enid 230kV (6 cy)Enid - N. Oakland 230kV (6 cy)N. Oakland - Tillatoba 230kV (6 cy)Batesville - Moon Lake 230kV (16 cy)Batesville Gen (LS Power) 230kV (16 cy)Batesville 230/115kV Transfm. (16 cy)

Fault 12A Batesville 230kV Bus 3PH-3PH

6 16 Batesville 230kV: J4404, J4410,J4432

Batesville 230kV: J4408 Moonlake 230kV: J8770,JXXXX

Batesville - LS Power 230kV (6 cy)Batesville 230/115kV Transfm. (6 cy)Batesville - Enid 230kV (6 cy)Enid - N. Oakland 230kV (6 cy)N. Oakland - Tillatoba 230kV (6 cy)Batesville - Moon Lake 230kV (16 cy)

Fault 14A Freeport - Birminham Steel500kV

3PH-1PH

5 14 Freeport 500kV: N/ABirminham Steel 500kV: N/A

Freeport 500kV: N/A Freeport 500kV: Freeport - Birminham Steel 500 kV (14 cy)

Notes:

1. All fault clearing times refer to the elapsed time from the instant of fault inception. i.e., 6 cy+10 cy = 16 cy and 5 cy+9 cy = 14 cy.2. All 500 kV breakers are IPO breakers. For simulation purposes, the 3-ph fault is converted to a single-line-to-ground fault at normal clearing time.

3. All breakers at <500 kV have a shared operating mechanism. The fault at the stuck breaker remains a 3-ph fault.

4. Substation drawings were not available for Fault 14A. It was assumed that a redundant breaker configuration is used, preventing the loss of any additional facilities.

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Figure 3.3: Moon Lake 230 kV Substation

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Figure 3.4: Clarksdale 230/115kV Substation

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Figure 3.5: Ritchie 230 kV Substation

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Figure 3.6: Batesville 230 kV Substation

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Figure 3.7: Tunica 230 kV Substation

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3.3.2 Stability ResultsTable 3.4 summarizes the simulation results for the three-phase normally cleared and stuck-breaker faults.

Table 3.4: Normally Cleared and Stuck Breaker Fault Simulation Results

Fault #Pre-Project Post-Project

Stability CriteriaSatisfied?

Voltage CriteriaSatisfied?

Stability CriteriaSatisfied?

Voltage CriteriaSatisfied?

Fault 1 YES YES YES YESFault 2 YES YES YES YESFault 3 YES YES YES YESFault 4 YES YES YES YESFault 5 YES YES YES YESFault 6 YES YES YES YESFault 7 YES YES YES YESFault 8 YES YES YES YESFault 9 YES YES YES YES

Fault 10 YES YES YES YESFault 11 YES YES YES YESFault 12 YES YES YES YESFault 13 YES YES YES YESFault 14 YES YES YES YESFault 15 YES YES YES YESFault 1A YES NO YES NOFault 2A YES NO YES NOFault 8A YES YES YES YES

Fault 11A NO NO NO NOFault 12A YES YES YES YESFault 14A YES YES YES YES

System Stability Analysis for Three-Phase and Three-Phase Stuck-Breaker Faults

First-swing instability was observed on the LS Power generators following Fault 11A. That is,the system was found to be UNSTABLE following Fault 11A, with LS Power generatorsswinging out of synchronism with the system. Fault 11A involves the loss of the Batesville –Enid – Oakland – Tillatoba 230 kV lines, the Batesvile – Moon Lake 230 kV line, the Batesville –LS Power 230 kV line, and the Batesville 115 / 230 kV Transformer following a three-phasestuck-breaker fault at the Batesville – Enid 230 kV line. Under post-fault conditions, the onlytransmission outlet for the 770 MW of generation from the LS Power units is the 161 kVBatesville bus. Such a large injection of power cannot be supported by this 161 kV network.LS Power generators rotor angles are shown in Figure 3.9 for Fault 11A. Five (5) of the six (6)LS Power units slip poles, as seen in Figure 3.9. Fault 11A was also seen to be unstable in the

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pre-project case, without the addition of the E001 Wind Farm. Given these results, the impact ofE001 on the system stability is not deemed significant for Fault 11A.

All other three-phase and three-phase stuck-breaker faults were found to be stable. Plots forselect stability simulations are included in Appendix C. As a representative example of a systemrecovery to stable conditions, Figure 3.8 shows the rotor angles for regional generatorsfollowing Fault 1, a normally cleared fault on the Moon Lake – Ritchie 230 kV branch at theMoon Lake bus.

Transient Voltage Recovery

The voltages at all buses in the Entergy system in the vicinity of the project were monitoredduring each of the simulated faults, and any violations of the Entergy voltage criteria werenoted.

As there are no specific voltage dip criteria for three-phase stuck-breaker faults, the results ofthese faults were compared with the most stringent voltage dip criteria, where the voltage dip isnot to exceed 20% of the pre-fault voltage for more than 20 cycles at any bus, not to exceed25% at load buses, and not to exceed 30% at any non-load bus. If the more stringent criteria isnot met, the following voltage criteria are observed: voltage dip is not to exceed 20% for morethan 40 cycles at any bus and not to exceed 30% at any bus. These voltage violations must bevery widespread during a specific fault for these criteria to be applied to stuck-breaker faults.

During Fault 1A, 2A, and 11A, bus voltages were found to be in violation of the above voltagecriteria in both pre-project and post-project cases. As discussed above, Fault 11A is first swingunstable, which causes system voltages to oscillate widely and results in numerous voltageviolations. These violations for 11A will not be discussed in detail, as instability has alreadybeen established. Faults 1A and 2A are both three-phase stuck breaker faults at the Moon Lake230 kV substation where the Moon Lake – Crossroads 230 kV line is tripped by backupprotection after 16 cycles. For Faults 1A and 2A, the minimum voltages at buses with a violationare listed in Table 3.5 for both pre- and post-project addition of E001. As seen in this table, theminimum voltage recorded for all buses after the fault is higher in the post simulations than thepre simulations. Given the above results, E001 does not adversely impact transient voltages inthe system.

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Table 3.5: Voltage Violations for Fault 1A

Bus # Bus NamePre-Fault

Voltage [pu]

Fault 1AMin Voltage

[pu]

Fault 1AVoltage Drop

[pu]PRE POST PRE POST PRE POST

337096 Roundaway 115kV 0.99 0.99 0.69 0.73 0.30 0.26337097 Shelby MS 115kV 0.99 0.99 0.72 0.76 0.27 0.23337098 Clarksdale Municipal 115kV 1.00 1.00 0.65 0.70 0.35 0.30337099 Clarksdale 115kV 1.00 1.00 0.65 0.70 0.35 0.30337100 Crossroads 230kV 1.01 1.01 0.63 0.63 0.38 0.38337102 Crossroads G1 13.8kV 1.00 1.00 0.64 0.65 0.36 0.35337103 Crossroads G2 13.8kV 1.00 1.00 0.64 0.65 0.36 0.35337105 Crossroads G3 13.8kV 1.00 1.00 0.64 0.65 0.36 0.35337106 Crossroads G4 13.8kV 1.00 1.00 0.64 0.65 0.36 0.35337110 Lyon 115kV 1.00 1.00 0.66 0.71 0.34 0.29337111 Jonestown 115kV 1.00 1.00 0.70 0.74 0.30 0.26337112 Jonestown 115kV 1.00 1.00 0.70 0.74 0.30 0.26

Table 3.6: Voltage Violations for Fault 2A

Bus # Bus NamePre-Fault

Voltage [pu]

Fault 2AMin Voltage

[pu]

Fault 2AVoltage Drop

[pu]PRE POST PRE POST PRE POST

337096 Roundaway 115kV 0.99 0.99 0.68 0.71 0.32 0.28337097 Shelby MS 115kV 0.99 0.99 0.71 0.74 0.28 0.25337098 Clarksdale Municipal 115kV 1.00 1.00 0.63 0.68 0.37 0.32337099 Clarksdale 115kV 1.00 1.00 0.63 0.68 0.37 0.32337100 Crossroads 230kV 1.01 1.01 0.62 0.62 0.39 0.39337102 Crossroads G1 13.8kV 1.00 1.00 0.64 0.64 0.37 0.36337103 Crossroads G2 13.8kV 1.00 1.00 0.64 0.64 0.37 0.36337105 Crossroads G3 13.8kV 1.00 1.00 0.64 0.64 0.37 0.36337106 Crossroads G4 13.8kV 1.00 1.00 0.64 0.64 0.37 0.36337110 Lyon 115kV 1.00 1.00 0.64 0.68 0.36 0.32337111 Jonestown 115kV 1.00 1.00 0.68 0.72 0.32 0.28337112 Jonestown 115kV 1.00 1.00 0.68 0.72 0.32 0.28

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It should be noted that in preparation of the dynamics files, the 45 MW Clarksdale Municipalgenerator, which is in the vicinity of these buses, has been converted to a negative load via thePSS/E function “GNET”. Therefore, it is possible that if this generator were modeled in detail itwould provide additional voltage support during the duration of the Fault 1A and 2A, reducingthe severity of these voltage depressions.

The Entergy Transmission Planning Criteria states that “transient voltage dip criteria may not beapplied to three-phase faults followed by a stuck breaker conditions unless the determinedimpact is extremely widespread.” Faults 1A and 2A are both three-phase stuck breaker faults,and it does not appear that these voltage violations are “extremely widespread”.

Stability and Voltage Analysis for Single-Line-to-Ground Stuck-Breaker Faults

Three-phase faults with stability and transient voltage violations were re-simulated ascorresponding single-line-to-ground (SLG) stuck-breaker faults. SLG stuck-breaker faults wereonly tested on the post-project case.

Specifically Fault 11A was simulated as equivalent SLG stuck-breaker faults, as shown in Table3.7. Additionally Faults 1A and 2A were simulated to verify that the transient voltage recoverycriteria are met. The voltage criteria applied to SLG stuck-breaker faults is that the postcontingency voltage dip is not to exceed 20% for more than 40 cycles and not to exceed 30% atany bus.

Fault 11A is stable and without voltage violations for SLG stuck-breaker faults. Also, Fault 1Aand Fault 2A continue to be stable as before and do not result in any voltage violations.

Table 3.7: Single-Line-to-Ground Stuck-Breaker Fault Simulation Results

Fault # Faulted Line TypeTotal Fault

Clearing Time(Cycles)

Tripped FacilitiesPost-Project

Stable? VoltageCriteria?Primary Backup

Fault 1A Moon Lake - Ritchie 230kV 1PH-1PH

6 16 Moon Lake - Ritchie 230kV (6 cy)Moon Lake - Crossroads 230kV (16 cy) Yes Yes

Fault 2A Moon Lake - Batesville 230kV1PH-1PH 6 16

Moon Lake - Batesville 230kV (6 cy)Moon Lake - Crossroads 230kV (16 cy) Yes Yes

Fault 11A Batesville - Enid 230kV1PH-1PH 5 14

Batesville - Moon Lake 230kVBatesville - LS Power 230kVBatesville 230/115kV Transfm.Batesville - Enid 230kVEnid - N. Oakland 230kVN. Oakland - Tillatoba 230kV

Yes Yes

20

ABB

Figure 3.8: Regional Generator Rotor Angles, Fault_1

21

ABB

Figure 3.9: LS Power Generator Angle Instability, Fault_11A

22

ABB

Figure 3.10: Buses in violation of voltage criteria, Fault_1A

23

ABB

Figure 3.11: Buses in violation of voltage criteria, Fault_2A

24

ABB

3.4 Low Voltage Ride ThroughAs discussed in Section 3.2, the proposed project was modeled with low voltage ride through(LVRT) capability. The Point-of-Interconnection (POI) of the proposed wind farm is the MoonLake 230 kV substation. The post-transition period LVRT capability of the project was verifiedby simulating three (3) separate three-phase faults at the 230kV POI, as listed in Table 3.8.

Table 3.8: Three Phase Faults for Low Voltage Ride Through Evaluation

Results from Fault 1-LVRT, Fault 2-LVRT, and Fault 3-LVRT are plotted in Figure 3.12 throughFigure 3.14. During all three (3) of these faults, the E001 wind farm remained online and did notdisconnect from the grid and is therefore compliant with the Low Voltage Ride-Throughrequirements mandated by FERC Order 661-A.

Fault # Faulted Line Type ClearingTime(Cy)

Primary Breakers Tripped Facilities

Fault 1-LVRT

Moon Lake - Ritchie 230kV 3 PH 9 Moon Lake 230kV: J8762, J8766Ritchie 230kV: B4788

Moon Lake - Ritchie 230kV

Fault 2-LVRT

Moon Lake - Batesville 230kV 3 PH 9 Moon Lake 230kV: J8770, JXXXXBatesville 230kV: J4408

Moon Lake - Batesville 230kV

Fault 3-LVRT

Moon Lake - Crossroads 230kV 3 PH 9 Moon Lake 230kV: JXXXX, J8762Crossroads 230kV: 2230_2

Moon Lake - Crossroads 230kV

25

ABB

Figure 3.12: LVRT Capability of E001 for Fault_1-LVRT

26

ABB


27

ABB


28

ABB

4 CONCLUSIONS

This study evaluated the impact of the proposed E001 (200 MW net) wind farm on system short-circuit and stability performance.

A summary of the study results is presented below.

Short-Circuit Analysis:Short-circuit analysis was performed using ASPEN models provided by Entergy. The focus ofthis analysis is to evaluate the impact of the proposed E001 project on fault duties atsubstations in the electrical vicinity of the proposed wind farm. Breaker fault duties werecomputed based on simulation of three-phase and single-line-to-ground faults. Entergy's short-circuit under-rated breaker rating methodology was used to identify impacted breakers.Comparison of the post-project fault duties against interrupting capabilities of existing breakersat substations in the local vicinity indicates that there is adequate interrupting capabilityfollowing the addition of the proposed wind farm.

Stability Analysis:Stability analysis was performed on a 2017 Summer Peak case provided by Entergy. Fifteen(15) three-phase normally cleared and six (6) three-phase stuck-breaker faults were simulatedto determine the impact of E001 on the stability and transient voltage recovery of the localEntergy System.

One (1) three-phase stuck-breaker fault at the Batesville 230 kV bus was found to be unstable.Further investigation on a pre-project case (without E001) showed similar results. Hence, it wasconcluded that the instability is not attributable to E001. The system was stable following allother simulated normally-cleared three-phase faults and three-phase stuck-breaker faults.

Also, transient voltage criteria violations were observed for two (2) other three-phase stuck-breaker faults in the pre- and post-project cases. The faults with voltage criteria violations werefor faults at the Moon Lake 230 kV bus where the Moon Lake – Crossroads 230 kV branch istripped as backup protection following a three-phase stuck-breaker fault. However, it has beendemonstrated that the violations exist prior to the addition of the E001 project, and that theimpact of E001 on the transient voltage violations following these faults is marginal.

Three-phase stuck breaker faults that exhibited stability or transient voltage violations, asdescribed in the preceding paragraphs, were re-simulated as corresponding single-line-to-ground (SLG) stuck-breaker faults. Results show no stability and transient voltage criteriaviolations for these faults.

The proposed project (E001) complies with FERC Order 661-A on low voltage ride through forwind farms. Results show that the proposed wind farm does not trip off-line by voltage relayactuation for local faults at the POI.

Based on the results of the above study, it can be concluded that the proposed E001 wind farmdoes not adversely impact the short-circuit or stability performance of the Entergy System.

The results of this study are based on available data and assumptions made at the time ofconducting the study. If any of the data and/or assumptions made in developing the studymodel change, the results provided in this report may not apply.

29

ABB

5 REFERENCED DOCUMENTS

1. Entergy Transmission Local Planning Criteria, February 25, 2007. Available at:https://www.oatioasis.com/woa/docs/EES/EESdocs/transmission_local_planning_criteria.pdf

https://www.oatioasis.com/woa/docs/EES/EESdocs/transmission_local_planning_criteria.pdf

https://www.oatioasis.com/woa/docs/EES/EESdocs/transmission_local_planning_criteria.pdf

30

ABB

APPENDIX A Data Provided by Customer

31

ABB

32

ABB

33

ABB

APPENDIX B PSS/E Dynamics Data

PTI INTERACTIVE POWER SYSTEM SIMULATOR--PSS/E THU, AUG 08 2013 16:06

PLANT MODELS

REPORT FOR ALL MODELS BUS 337118 [1MOON 0.6900] MODELS

** W4GUR2 ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S V A R S 337118 1MOON 0.6900 1 20634-20642 9329-9331 39-43

TIqCmd TIpCmd VLVPL1 VLVPL2 GLVPL 0.0100 0.0200 0.4000 -0.1000 1.1100

VHVRCR CURHVRCR RIp_LVPL T_LVPL 1.2500 2.0000 2.0000 0.0200

** W4EUR2 ** BUS X-- NAME --X BASEKV MC C O N S S T A T E S V A R S I C O N S 337118 1MOON 0.6900 1 83297-83330 37925-37935 3547-3550 4245-4248

TFV KPV KIV KPP 0.0000 15.0000 2.0000 0.0800

KIP Kf Tf QMX QMN IPMAX TRV 0.0100 0.0000 0.0800 1.0000 -1.2000 1.1000 0.0000

dPMX dPMN T_POWER KQi VMINCL VMAXCL Kvi 0.5000 -0.5000 0.0500 0.0100 0.8750 1.1250 55.0000

Tv Tp ImaxTD Iph1 Iqh1 0.0500 0.0500 1.1150 1.2500 1.0850

Tiqf FRT_Thres FRT_Hys FRT_Droop FRT_Iq_Gain 0.0200 0.8750 0.0500 0.0000 2.0000

Max_FRT_Iq IQMax_Fact1 IQMax_Fact2 1.0000 1.0000 1.0000

DC_Link_Droop VinvMax0 NBR_X 1.0000 1.1000 0.1415

ICON(M) - Remote controlled Bus : 337118 ICON(M+1) - PFAFLG = 0 (1 if PF fast control is enabled; else 0) ICON(M+2) - VARFLG = 1 (1 if Qcmd is provided by WindVar; else 0) ICON(M+3) - PQFLAG = 0 (1 for P priority, =0 for Q priority)


CONEC MODELS


*** CALL WT4PLT( 6809, 0, 0, 14413) ***

** WT4PLT ** BUS X-- NAME --X BASEKV MC V A R S ICONS

34

ABB

337118 1MOON 0.69 1 14413-14421 6809-6810

Wind generator Bus # 337118 Wind Generator ID 1


CONET MODELS


*** CALL VTGTPA( 7117,154403, 0, 14481) ***

BUS NAME BSKV GENR BUS NAME BSKV ID 337108 6MOON 230 337118 1MOON .690 1

I C O N S C O N S V A R 7117-7122 154403-154406 14481

VLO VUP PICKUP TB 0.900 5.000 200.000 0.050

*** CALL VTGTPA( 7123,154407, 0, 14482) ***


I C O N S C O N S V A R 7123-7128 154407-154410 14482

VLO VUP PICKUP TB 0.850 5.000 3.000 0.050

*** CALL VTGTPA( 7129,154411, 0, 14483) ***


I C O N S C O N S V A R 7129-7134 154411-154414 14483

VLO VUP PICKUP TB 0.700 5.000 2.600 0.050

*** CALL VTGTPA( 7135,154415, 0, 14484) ***


I C O N S C O N S V A R 7135-7140 154415-154418 14484

VLO VUP PICKUP TB 0.400 5.000 1.600 0.050

*** CALL VTGTPA( 7141,154419, 0, 14485) ***


I C O N S C O N S V A R 7141-7146 154419-154422 14485

35

ABB

VLO VUP PICKUP TB 0.150 5.000 0.850 0.050

*** CALL VTGTPA( 7147,154423, 0, 14486) ***


I C O N S C O N S V A R 7147-7152 154423-154426 14486

VLO VUP PICKUP TB 0.000 1.100 1.000 0.050

*** CALL VTGTPA( 7153,154427, 0, 14487) ***


I C O N S C O N S V A R 7153-7158 154427-154430 14487

VLO VUP PICKUP TB 0.000 1.200 0.150 0.050

*** CALL FRQTPA( 7159,154431, 0, 14488) ***

BUS NAME BSKV GEN BUS NAME BSKV ID 337108 6MOON 230 337118 1MOON .690 1

I C O N S C O N S V A R 7159-7164 154431-154434 14488

FLO FUP PICKUP TB 57.000 100.000 0.200 0.000

*** CALL FRQTPA( 7165,154435, 0, 14489) ***

BUS NAME BSKV GEN BUS NAME BSKV ID 337108 6MOON 230 337118 1MOON .690 1

I C O N S C O N S V A R 7165-7170 154435-154438 14489

FLO FUP PICKUP TB 0.000 62.000 0.200 0.000

36

ABB

APPENDIX C Plots for Stability Simulations

37

ABB

APPENDIX C.1 Pre-Project Fault Plots

List of Figures:

Pre-project, Fault_1

Pre-project, Fault_1A

Pre-project, Fault_1A-SLG







CHNL# 108: [ANGLE - 1RITCHIE U2 18.000]200.00 0.0

CHNL# 67: [ANGLE - 1CROSSRDS G213.800]200.00 0.0

CHNL# 65: [ANGLE - 3CLRKD MUNI!115.00]200.00 0.0

CHNL# 111: [ANGLE - 1LSPWRU1 13.800]200.00 0.0

CHNL# 71: [ANGLE - 1SLSBAU3 13.800]200.00 0.0

CHNL# 72: [ANGLE - 1CLSBAU3 18.000]200.00 0.0

FAULT 1, MOONLAKE - RITCHIE 230KV, NORMALLY CLEARED, 3PHPRE - WF DISCONNECTED

TUE, AUG 13 2013 14:14

TIME (SECONDS)

SIEMENS POWERTECHNOLOGIESINTERNATIONAL R

0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000

FILE: FaultsOut-Pre\FAULT_1_Test05.out

LOCAL ROTOR ANGLES

CHNL# 148: [ANGLE - 1ALLEN F1 24.000]200.00 0.0

CHNL# 499: [ANGLE - 1S HAVEN T1 18.000]200.00 0.0

CHNL# 502: [ANGLE - 1S HAVEN S1 13.800]200.00 0.0

CHNL# 82: [ANGLE - 1WHT BLUF U226.000]200.00 0.0

CHNL# 122: [ANGLE - 1WRIGHTS C1 13.800]200.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 MACHINE P & Q COMMAN

CHNL# 3245: [VOLT-BUS 337118, E001 TERM]1.2000 0.20000

CHNL# 3244: [VOLT-BUS 337117, GSU 34.5KV]1.2000 0.20000


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE

CHNL# 3234: [VOLT-BUS 337107, 6MOONLAKE]1.2000 0.20000

CHNL# 3588: [VOLT-BUS 337991, 6RITCHIE-2]1.2000 0.20000

CHNL# 3229: [VOLT-BUS 337100, 6CROSSROADS]1.2000 0.20000

CHNL# 3273: [VOLT-BUS 337160, 6TUNICA]1.2000 0.20000

CHNL# 3249: [VOLT-BUS 337123, 6BATESVILLE]1.2000 0.20000

CHNL# 3275: [VOLT-BUS 337162, 6FREEPORT]1.2000 0.20000


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV


CHNL# 3227: [VOLT-BUS 337098, 3CLRKD MUNI]1.2000 0.20000


CHNL# 3584: [VOLT-BUS 337986, 3RITCHIE]1.2000 0.20000

CHNL# 3571: [VOLT-BUS 337967, 3RICUSKEY]1.2000 0.20000


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV


CHNL# 3934: [VOLT-BUS 360075, 8BHAM STEEL]1.2000 0.20000

CHNL# 3891: [VOLT-BUS 360025, 8CORDOVA]1.2000 0.20000

CHNL# 3674: [VOLT-BUS 338162, 8W.MEMPHIS]1.2000 0.20000

CHNL# 3689: [VOLT-BUS 338187, 8DELL]1.2000 0.20000


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV

CHNL# 21: [FLWP - MOONLAKE TO E001]500.00 -500.0

CHNL# 23: [FLWP - MOONLAKE TO RITCHIE]500.00 -500.0

CHNL# 25: [FLWP - MOONLAKE TO BATESVILLE]500.00 -500.0

CHNL# 27: [FLWP - MOONLAKE TO CROSSROADS]500.00 -500.0

CHNL# 29: [FLWP - RITCHIE TO TUNICA]500.00 -500.0

CHNL# 35: [FLWP - BATESVILLE TO ENID]500.00 -500.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW

CHNL# 22: [FLWQ - MOONLAKE TO E001]500.00 -500.0

CHNL# 24: [FLWQ - MOONLAKE TO RITCHIE]500.00 -500.0

CHNL# 26: [FLWQ - MOONLAKE TO BATESVILLE]500.00 -500.0

CHNL# 28: [FLWQ - MOONLAKE TO CROSSROADS]500.00 -500.0

CHNL# 30: [FLWQ - RITCHIE TO TUNICA]500.00 -500.0

CHNL# 36: [FLWQ - BATESVILLE TO ENID]500.00 -500.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 1A, MOON LAKE - RITCHIE 230KV, STUCK BREAKER, 3PH-3PHPRE - WF DISCONNECTED

TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000

FILE: FaultsOut-Pre\FAULT_1A_Test05.out

LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 1A-SLG, MOON LAKE - RITCHIE 230KV, STUCK BREAKER, 1PH-PRE - WF DISCONNECTED

TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000

FILE: FaultsOut-Pre\FAULT_1B_Test05.out

LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 2, MOONLAKE - BATESVILLE 230KV, NORMALLY CLEARED, 3PHPRE - WF DISCONNECTED

TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 2A, MOON LAKE - BATESVILLE 230KV, STUCK BREAKER, 3PH-3PRE - WF DISCONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 2A-SLG, MOON LAKE - BATESVILLE 230KV, STUCK BREAKER, 1PRE - WF DISCONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 11, BATESVILLE - ENID 230KV, NORMALLY CLEARED, 3PHPRE - WF DISCONNECTED

TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:14

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 11A, BATESVILLE - ENID 230KV, STUCK BREAKER, 3PH-3PHPRE - WF DISCONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 11A-SLG, BATESVILLE - ENID 230KV, STUCK BREAKER, 1PH-1PRE - WF DISCONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW

38

ABB

APPENDIX C.2 Post-Project Fault Plots

List of Figures:

Post-project, Fault_1

Post-project, Fault_1A

Post-project, Fault_1A-SLG













FAULT 1, MOONLAKE - RITCHIE 230KV, NORMALLY CLEARED, 3PHPOST - WF CONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000

FILE: FaultsOut-Post\FAULT_1_Test05.out

LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 1A, MOON LAKE - RITCHIE 230KV, STUCK BREAKER, 3PH-3PHPOST - WF CONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000

FILE: FaultsOut-Post\FAULT_1A_Test05.out

LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 1A-SLG, MOON LAKE - RITCHIE 230KV, STUCK BREAKER, 1PH-POST - WF CONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000

FILE: FaultsOut-Post\FAULT_1B_Test05.out

LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 2, MOONLAKE - BATESVILLE 230KV, NORMALLY CLEARED, 3PHPOST - WF CONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 2A, MOON LAKE - BATESVILLE 230KV, STUCK BREAKER, 3PH-3POST - WF CONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 2A-SLG, MOON LAKE - BATESVILLE 230KV, STUCK BREAKER, 1POST - WF CONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 11, BATESVILLE - ENID 230KV, NORMALLY CLEARED, 3PHPOST - WF CONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 11A, BATESVILLE - ENID 230KV, STUCK BREAKER, 3PH-3PHPOST - WF CONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW







FAULT 11A-SLG, BATESVILLE - ENID 230KV, STUCK BREAKER, 1PH-1POST - WF CONNECTED

TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL ROTOR ANGLES







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


REMOTE ROTOR ANGLES

CHNL# 1523: 100*[PELEC - 1MOON 0.6900]300.00 0.0

CHNL# 2008: 222.37*[PMECH - 1MOON 0.6900]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 PELEC, PMECH

CHNL# 19: 222.37*[VAR 14413]300.00 0.0

CHNL# 20: 222.37*[VAR 14414]300.00 0.0


TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


E001 VOLTAGE








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 230KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL 115KV







TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


500 KV








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL P BRANCH FLOW








TUE, AUG 13 2013 14:15

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000


LOCAL Q BRANCH FLOW

39

ABB

APPENDIX D Short-Circuit Results

40

ABB

APPENDIX D.1 Fault Duties without Priors

Table shows substations where the impact on fault duties due to the proposed E001 project is 50 Amp or larger.

Pre-projectCase Post-ProjectCase %DutyDutyAmp

BUS_NO BUS BREAKER RATINGTYPE %DutyDuty(Amp) BKR_CAPA %Duty Duty(Amp) Diff Diff

337123 BATES230.kV J4410-ICO S 23 14505.3 63000 23.1 14576.5 0.1 71.2

337123 BATES230.kV J4432-ICO S 26.1 10437.1 40000 26.3 10508.6 0.2 71.5337100 MEPCLKAUTO230.kV @MEPCLKAUT S 35.9 14366.3 40000.0 36.2 14473.1 0.3 106.8337107 MOONLAKE230.kV J8762-C S 26.5 10588.1 40000.0 28.6 11457.6 2.1 869.5337107 MOONLAKE230.kV J8766-C S 18.7 7474.5 40000.0 20.2 8096.8 1.5 622.3337107 MOONLAKE230.kV J8770-C S 26.5 10588.1 40000.0 28.6 11457.6 2.1 869.5

337998 RITCHI230.kV B4401-C S 43.5 17402.7 40000.0 44.6 17825.6 1.1 422.9337998 RITCHI230.kV B4422-TICO T 53.4 20112.4 37653.3 54.0 20331.7 0.6 219.3337998 RITCHI230.kV B4430-TIC T 44.2 16630.2 37653.3 44.8 16861.4 0.6 231.2337998 RITCHI230.kV B4744-TICO T 53.0 19966.9 37653.3 53.6 20189.3 0.6 222.4337998 RITCHI230.kV B5144-TICO T 47.8 18013.9 37653.3 48.4 18240.4 0.6 226.5

337998 RITCHI230.kV B8044-TICO T 53.4 20112.4 37653.3 54.0 20331.7 0.6 219.3337998 RITCHI230.kV B9721-TICO T 56.4 21252.8 37653.3 57.3 21559.7 0.9 306.9337998 RITCHI230.kV B9722-TICO T 43.9 16527.8 37653.3 45.3 17040.9 1.4 513.1337160 TUNICA230.kV J2704-CO S 23.5 9414.4 40000 23.7 9468.2 0.2 53.8337160 TUNICA230.kV J2712-CO S 16.7 6686.6 40000 16.9 6747.4 0.2 60.8

41

ABB

APPENDIX D.2 Fault Duties with Priors PID-247, PID-289 and PID-291

Table shows substations where the impact on fault duties due to the proposed E001 project is 50 Amp or larger.

Pre-projectCase Post-ProjectCase %DutyDutyAmp

BUS_NO BUS BREAKER RATINGTYPE %Duty Duty(Amp) BKR_CAPA %Duty Duty(Amp) Diff Diff337123 BATES230.kV J4410-ICO S 23.0 14505.3 63000.0 23.1 14576.5 0.1 71.2337123 BATES230.kV J4432-ICO S 26.1 10437.1 40000.0 26.3 10508.6 0.2 71.5

337100 MEPCLKAUTO230.kV @MEPCLKAUT S 35.9 14366.3 10000.0 36.2 14473.1 0.3 106.8337107 MOONLAKE230.kV J8762-C S 26.5 10588.1 40000.0 28.6 11457.6 2.1 869.5337107 MOONLAKE230.kV J8766-C S 18.7 7474.5 40000.0 20.2 8096.8 1.5 622.3337107 MOONLAKE230.kV J8770-C S 26.5 10588.1 40000.0 28.6 11457.6 2.1 869.5

337998 RITCHI230.kV B4401-C S 43.5 17402.7 40000.0 44.6 17825.6 1.1 422.9337998 RITCHI230.kV B4422-TICO T 53.4 20112.4 37653.3 54.0 20331.7 0.6 219.3337998 RITCHI230.kV B4430-TIC T 44.2 16630.2 37653.3 44.8 16861.4 0.6 231.2337998 RITCHI230.kV B4744-TICO T 53.0 19966.9 37653.3 53.6 20189.3 0.6 222.4337998 RITCHI230.kV B5144-TICO T 47.8 18013.9 37653.3 48.4 18240.4 0.6 226.5

337998 RITCHI230.kV B8044-TICO T 53.4 20112.4 37653.3 54.0 20331.7 0.6 219.3337998 RITCHI230.kV B9721-TICO T 56.4 21252.8 37653.3 57.3 21559.7 0.9 306.9337998 RITCHI230.kV B9722-TICO T 43.9 16527.8 37653.3 45.3 17040.9 1.4 513.1337160 TUNICA230.kV J2704-CO S 23.5 9414.4 40000.0 23.7 9468.2 0.2 53.8337160 TUNICA230.kV J2712-CO S 16.7 6686.6 40000.0 16.9 6747.4 0.2 60.8

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