system impact study for e001 - · pdf fileiv the system was stable following all other...

POWER SYSTEMS CONSULTING

SYSTEM IMPACT STUDY FOR E001

FINAL REPORT

REPORT NO.: 2013-E11415-R2

Issued On: September 25, 2013

Prepared for:

Midcontinent Independent System Operator, Inc.

Prepared by:

ABB Inc.

Power Systems Consulting

940 Main Campus Drive, Suite 300

Raleigh, NC 27606

12 Cornell Road

Latham, NY 12110

Legal Notice This document, prepared by ABB Inc. (ABB), is an account of work sponsored by Midcontinent Independent System Operator, Inc. (MISO). Neither MISO nor ABB nor any person or persons acting 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 any information, apparatus, method, or process disclosed in this report may not infringe privately owned rights, or (ii) assumes any liabilities with respect to the use of or for damages resulting from 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-R2

System Impact Study for E001

September 25, 2013 # Pages

31

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 study for Project E001, which is an interconnection request for a proposed 200 MW wind farm in the Entergy service territory. The proposed project has requested interconnection at the Moon Lake 230 kV substation. The objective of this study is to determine if the interconnection of E001 would result in adverse short-circuit or stability impacts on the Entergy system. 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 of this analysis is to evaluate the impact of the proposed E001 project on fault duties at substations in the electrical vicinity of the proposed wind farm. Breaker fault duties were computed 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 breakers at substations in the local vicinity indicates that there is adequate interrupting capability following 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 simulated to determine the impact of E001 on the stability and transient voltage recovery of the local Entergy System. Two (2) three-phase stuck-breaker faults at the Moon Lake 230 kV bus were found to be unstable in the pre-project case (without E001). These faults were marginally stable in the post-project case (with E001), but transient voltage violations were observed. Based on these results, it can be concluded that E001 does not further degrade system stability for these faults. 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 was concluded that the instability is not attributable to E001.

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The system was stable following all other simulated normally-cleared three-phase faults and three-phase stuck-breaker faults. Three-phase stuck breaker faults that exhibited stability or transient voltage violations, as described in the preceding paragraphs, were re-simulated as corresponding single-line-to-ground (SLG) stuck-breaker faults. Results show no stability and transient voltage criteria violations for these faults. The proposed project (E001) complies with FERC Order 661-A on low voltage ride through for wind farms. Results show that the proposed wind farm does not trip off-line by voltage relay actuation for local faults at the POI. Based on the results of the above study, it can be concluded that the proposed E001 wind farm does 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 ......................................................................................... 5

3.2.2 Stability Database ...................................................................................... 5

3.3 TRANSIENT STABILITY RESULTS AND ANALYSIS ................................ 9

3.3.1 Fault Definitions and Procedures ................................................................ 9

3.3.2 Stability Results .........................................................................................17

3.4 Low Voltage Ride Through ........................................................................26

4 CONCLUSIONS ............................................................................. 30

5 REFERENCED DOCUMENTS ....................................................... 31

APPENDIX A Data Provided by Customer ........................................................... 32

APPENDIX B PSS/E Dynamics Data ................................................................... 35

APPENDIX C Plots for Stability Simulations ......................................................... 38

APPENDIX D Short-Circuit Results ...................................................................... 41

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1 INTRODUCTION MISO has requested ABB Power Systems Consulting perform a short-circuit and stability study for Project E001, which is an interconnection request for a proposed 200 MW wind farm in the Entergy service territory. The proposed project has requested interconnection at the Moon Lake 230kV substation. The objective of this study is to determine if the interconnection of E001 would result in any adverse 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 230kV POI for E001

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2.1 PROJECT DESCRIPTION

The proposed E001 project will be located in the Entergy service territory. Power will be generated from 87 Siemens 2.3 MW wind turbines generators. The following list summarizes the major project parameters: Point of Interconnection: Moon Lake 230kV substation General:

Wind Farm Gross MW: 200 MW Number of Turbines: 87

Wind Turbine Generator: Manufacturer: Siemens Model: SWT2.3-VS 120 MVA: 2.3 MVA Type: 4, Full Converter Interface Rated Terminal Voltage: 690 V Frequency: 60 Hz Power Factor: 0.9 lagging – 0.9 leading

Generator Step-up Transformer (GSU):

Capacity: 2.6 MVA High voltage: 34.5 kV Low voltage: 0.69 kV Z: 5.7% on 2.6 MVA base, X/R = 7.1

Collector System Equivalent Impedance: System Voltage: 34.5 kV R: 0.1622 pu on 100 MVA base X: 0.2991 pu on 100 MVA base B: 0.09572 pu on 100 MVA base Substation Transformer: Capacity: 130/165/210 MVA

High Voltage: 230 kV Low Voltage: 34.5 kV Z: 10.049% on 130 MVA base, X/R = 63

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2 SHORT-CIRCUIT ANALYSIS

2.2 METHODOLOGY AND CRITERIA

The purpose of short-circuit analysis is to determine fault current levels at the point of interconnection, both before and after the addition of the proposed E001 project. Three-phase and single-line-to-ground faults were simulated at the point of interconnection and at nearby substations to determine the impact of the proposed project on fault duties and to identify overdutied breakers, if any, as a result of fault current contributions from the proposed project.

2.3 MODELS

Entergy provided two (2) pre-project ASPENTM models for the short-circuit analysis. It is understood that these models includes all generators interconnected to the Entergy system and interconnected 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 the corresponding post-project models. Two models were developed, one without priors and one with priors (PID-247, PID-289 and PID-291).

2.4 SHORT-CIRCUIT ANALYSIS

Short-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 fault duties were tabulated and compared against interrupting capabilities of breakers at nearby substations. Entergy's short-circuit under-rated breaker rating methodology was used to assess the 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-project fault duties against interrupting capabilities of existing breakers at substations in the local vicinity (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 addition of the proposed project.

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3 STABILITY ANALYSIS

3.1 STABILITY ANALYSIS ASSUMPTIONS, METHODOLOGY, AND CRITERIA

Stability 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 assumed that all 500kV breakers are Independent Pole Operated (IPO) and that the three phases of the breaker operate independently. Thus for faults involving a 500 kV breaker failure only a single phase 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 as it imparts a big shock to the generator shaft and may reduce its life span. Any deviation of rotor angle beyond 180 degrees is considered instability of the generator. It needs to be evaluated whether the instability is limited to a specific generator 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 of a 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 more

components (generator, transmission circuit or transformer), and SLG fault with delayed 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. The

transient voltage dip criteria may not be applied to three-phase faults followed by stuck breaker conditions unless the determined impact is extremely widespread.

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

Voltage dip monitoring is initiated two cycles following fault clearing (i.e., voltage dip criteria is not monitored for the duration of the fault). For the purposes of determining the voltage limits during three-phase and single-line-ground faults with normal clearing, a load bus is defined as any bus with one or more directly connected loads in the PSS/E case. Conversely, any bus without 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 transient voltage response of these faults were compared against the most stringent voltage dip criteria where voltage dip is not to exceed more than 20% of the pre-fault voltage for more than 20 cycles at any bus, not to exceed 25% at any load bus, and not to exceed 30% at any non-load bus. 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 to exceed 20% for more than 40 cycles at any bus and not to exceed 30% at any bus.

3.2 STUDY MODEL DEVELOPMENT

The E001 Wind farm is composed of 87 wind turbines, each with a rating of 2.3 MW. Each turbine is connected to a 0.69/34.5kV padmount step-up transformer. The 87 wind turbines are connected to a wind farm collector network, which is then connected to the Moon Lake 230kV bus 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 a gross power output of 200 MW. The voltage at the wind turbine terminal is 690 V and is stepped up to 34.5 kV through generator step-up transformer, which is connected to the point of interconnection 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 power to/from the grid thus contributing to grid voltage support. The WTG reactive power capability corresponds 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 in APPENDIX 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 Case

A powerflow case “EN17S12_U2_CP_final_V30_unconv.sav” representing 2017 Summer Peak conditions was provided by Entergy. The post-project powerflow case was provided by Entergy, and included E001 Wind Farm model interconnected at the Moon Lake 230 kV substation. To create a pre-project case without E001, the E001 generator bus, 34.5 kV collector system buses, 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 for the local area without and with the E001 project, respectively. During model development, it was noticed that the impedance values were suspect for the two (2) Crossroads GSU transformers connected to Bus #337100, leading to abnormal reactive power generation by the transformers. These impedance values for the two (2) transformers were updated in the PSS/E powerflow case to reflect the values in the ASPEN project models described in Section 2. These updated values resulted in logical power flows through the transformers.

3.2.2 Stability Database

PSS/E basecase stability database files were provided by Entergy. Specifically, the files provided included red16S_newnum.dyr and drift.snp. These files included stability data and models for E001. The E001 wind farm is modeled with all 87 wind turbines lumped into a single generator model in PSS/E using a generic type 4 wind turbine model. The generator/converter model used was

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W4GUR2 and the control model was W4EUR2, with parameters set for this specific Siemens wind turbine being used, as detailed in APPENDIX B. The voltage and frequency ride through capability of the wind farm is modeled by a series of under/over voltage relays using the VTGDCA model and under/over frequency relays using the FRQDCA 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 Procedures

Stability simulations were run to examine the transient behavior of the E001 generation and its impact 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-breaker faults were simulated. If the stability and/or transient voltage criteria were not met for a given fault 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 Clearing

115 6 cycles 6+10 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-phase normal clearing and three-phase stuck breaker faults, respectively. Fifteen (15) three-phase normally cleared and six (6) three-phase stuck-breaker faults were simulated. Figure 3.3 through Figure 3.7 show the breaker layout diagrams for substations where faults were simulated. 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, J8766

Ritchie 230kV: B4788

Moon Lake - Ritchie 230kV

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

Batesville 230kV: J4408

Moon Lake - Batesville 230kV

Fault 3 Moon Lake - Crossroads 230kV 3 PH 6 Moon Lake 230kV: JXXXX, J8762

Crossroads 230kV: 2230_2

Moon Lake - Crossroads 230kV

Fault 4 Crossroads - Clarksdale Transfm. 3 PH 6 Crossroads 230kV: 2230_5

Clarksdale 115kV: 3115_2

Crossroads - Clarksdale Transfm.

Fault 5 Ritchie - Tunica 230kV 3 PH 6 Ritchie 230kV: B5144

Tunica 230kV: J2716

Ritchie - Tunica 230kV

Fault 6 Ritchie - Aubrey 230kV 3 PH 6 Ritchie 230kV: B8044

Brinkley 230kV: B7600

Ritchie - Aubrey 230kV

Aubrey - Brinkley E. 230kV

Fault 7 Ritchie - Stuttgart Ricuskey 230kV 3 PH 6 Ritchie 230kV: B4744

Stuttgart 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 230kV

Ritchie Gen #2

Ritchie - Aubrey 230kV

Aubrey - Brinkley E. 230kV

Fault 9 Ritchie 230/115kV Transfm. 3 PH 6 Ritchie 230 kV: B4401

Ritchie 115 kV: B4402

Ritchie 230/115kV Transfm.

Fault 10 Batesville - LS Power 230kV 3 PH 6 Batesville 230kV: J4432

LS Power 230kV: 161_13, 161_9

Batesville - LS Power 230kV

Fault 11 Batesville - Enid 230kV 3 PH 6 Batesville 230kV: J4404

Tillatoba 230kV: J2524

Batesville - Enid 230kV

Enid - N. Oakland 230kV

N. Oakland - Tillatoba 230kV

Fault 12 Batesville 230kV Bus 3 PH 6 Batesville 230kV: J4404, J4408, J4410, J4432 Batesville - Moon Lake 230kV


Batesville 230/115kV Transfm.




Fault 13 Tunica - Robinsonville 230kV 3 PH 6 Tunica 230kV: J5408

Twinkletown 230kV: J7320

Tunica - Robinsonville 230kV

Robinsonville -Twinkletown 230kV

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

Birminham Steel 500kV: N/A

Freeport - Birminham Steel 500kV

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

Cordova 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 Type

Total Fault Clearing

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

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

3PH

6 16 Moon Lake 230kV: J8766


Moon Lake 230kV: J8762 Moon Lake 230kV: JXXXX


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: J8770


Moon Lake 230kV: JXXXX Moon Lake 230kV: J8762

Crossroads 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 Steel

500kV

3PH-

1PH

5 14 Freeport 500kV: N/A

Birminham 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 Results

Table 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 Criteria

Satisfied?

Voltage Criteria

Satisfied?

Stability Criteria

Satisfied?

Voltage Criteria

Satisfied?

Fault 1 YES YES YES YES















Fault 1A NO NO YES NO

Fault 2A NO NO YES NO

Fault 8A YES YES YES YES

Fault 11A NO NO NO NO



System Stability Analysis for Three-Phase and Three-Phase Stuck-Breaker Faults First-swing instability was observed on the Crossroads generators following Fault 1A and 2A in the pre-project case. That is, the system was found to be UNSTABLE in the pre-project case following Fault 1A and 2A, with the Crossroads generators swinging out of synchronism with the system. Fault 1A involves the loss of the Moon Lake – Ritchie 230 kV line and Moon Lake – Crossroads 230 kV line following a three-phase stuck breaker fault on the Moon Lake – Ritchie 230 kV line. Fault 2A involves the loss of the Moon Lake – Batesville 230 kV line and the Moon Lake – Crossroads 230 kV line following the three-phase stuck breaker fault on the Moon Lake – Batesville 230 kV line. The post-project case simulations for Fault 1A and 2A are marginally stable. That is, the Crossroads generators exhibit large rotor angle deviations, but do not slip poles during Fault 1A

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and 2A in the post-project case as seen in Figure 3.9 and Figure 3.11. The reason for the difference in stability results for the pre-project and post-project cases can be described as follows: In the post-project case, the Crossroads generators are generating slightly more reactive power in steady state conditions compared to the pre-project case. This requires a higher internal machine voltage for the Crossroads generators in the post-project case, which reduces their initial rotor angle under steady state conditions. The lower rotor angle in the post-project case marginally improves the rotor angle stability during Faults 1A and 2A. Given these results, the impact of E001 on the system stability is not deemed significant for Fault 1A and Fault 2A. 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 generators swinging 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-phase stuck-breaker fault on the Batesville – Enid 230 kV line. Under post-fault conditions, the only transmission outlet for the 770 MW of generation from the LS Power units is the 161 kV Batesville bus. Such a large injection of power cannot be supported by this 161 kV network. LS Power generators rotor angles are shown in Figure 3.13 for Fault 11A. Five (5) of the six (6) LS Power units slip poles, as seen in Figure 3.13. Fault 11A was also seen to be unstable in the pre-project case, without the addition of the E001 Wind Farm. Given these results, the impact of E001 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 for select stability simulations are included in Appendix C. As a representative example of a system recovery to stable conditions, Figure 3.8 shows the rotor angles for regional generators following Fault 1, a normally cleared fault on the Moon Lake – Ritchie 230 kV branch at the Moon Lake bus. Transient Voltage Recovery The voltages at all buses in the Entergy system in the vicinity of the project were monitored during each of the simulated faults, and any violations of the Entergy voltage criteria were noted. As there are no specific voltage dip criteria for three-phase stuck-breaker faults, the results of these faults were compared with the most stringent voltage dip criteria, where the voltage dip is not to exceed 20% of the pre-fault voltage for more than 20 cycles at any bus, not to exceed 25% at load buses, and not to exceed 30% at any non-load bus. If the more stringent criteria is not met, the following voltage criteria are observed: voltage dip is not to exceed 20% for more than 40 cycles at any bus and not to exceed 30% at any bus. These voltage violations must be very widespread during a specific fault for these criteria to be applied to stuck-breaker faults. During Faults 1A, 2A, and 11A, bus voltages were found to be in violation of the above voltage criteria in both pre-project and post-project cases. As discussed above, these faults are all first swing unstable, which causes system voltages to oscillate widely and results in numerous voltage violations. These violations for 1A, 2A, and 11A will not be discussed in detail, as instability has already been established and it has been determined that E001 does not adversely impact stability in the system.

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While the post-project simulations for Faults 1A and 2A exhibit marginal rotor angle stability, voltage criteria violations are observed during these faults. Faults 1A and 2A are both three-phase stuck breaker faults at the Moon Lake 230 kV substation where the Moon Lake – Crossroads 230 kV line is tripped by backup protection after 16 cycles. The Entergy Transmission Planning Criteria states that “transient voltage dip criteria may not be applied to three-phase faults followed by a stuck breaker conditions unless the determined impact 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 as corresponding single-line-to-ground (SLG) stuck-breaker faults. SLG stuck-breaker faults were only tested on the post-project case. Specifically Faults 1A, 2A, and 11A were simulated as equivalent SLG stuck-breaker faults, as shown in Table 3.5. The voltage criteria applied to SLG stuck-breaker faults is that the post contingency voltage dip is not to exceed 20% for more than 40 cycles and not to exceed 30% at any bus. Faults 1A, 2A, and 11A are stable and without voltage violations for SLG stuck-breaker faults.

Table 3.5: Single-Line-to-Ground Stuck-Breaker Fault Simulation Results

Fault #

Faulted Line

Type

Total Fault

Clearing Time

(Cycles)

Tripped Facilities

Post-Project

Stable? Voltage

Criteria? 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 230kV 1PH-

1PH 6 16

Moon Lake - Batesville 230kV (6 cy)

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

Fault 11A Batesville - Enid 230kV 1PH-

1PH 5 14

Batesville - Moon Lake 230kV


Batesville 230/115kV Transfm.




Yes Yes

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Figure 3.8: Regional Generator Rotor Angles, Fault_1, Post-Project Case

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Figure 3.9: Regional Generator Rotor Angles, Fault_1A, Post-Project Case

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Figure 3.10: Regional 115 kV Network Voltages, Fault_1A, Post-Project Case

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Figure 3.11: Regional Generator Rotor Angles, Fault_2A, Post-Project Case

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Figure 3.12: Regional 115 kV Network Voltages, Fault_2A, Post-Project Case

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Figure 3.13: LS Power Generator Angle Instability, Fault_11A, Post-Project Case

26

3.4 Low Voltage Ride Through

As 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 Moon Lake 230 kV substation. The post-transition period LVRT capability of the project was verified by simulating three (3) separate three-phase faults at the 230kV POI, as listed in Table 3.6.

Table 3.6: 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 3.14 through Figure 3.16. During all three (3) of these faults, the E001 wind farm remained online and did not disconnect from the grid and is therefore compliant with the Low Voltage Ride-Through requirements mandated by FERC Order 661-A.

Fault # Faulted Line Type Clearing

Time

(Cy)

Primary Breakers Tripped Facilities

Fault 1-

LVRT

Moon Lake - Ritchie 230kV 3 PH 9 Moon Lake 230kV: J8762, J8766


Moon Lake - Ritchie 230kV

Fault 2-

LVRT

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


Moon Lake - Batesville 230kV

Fault 3-

LVRT

Moon Lake - Crossroads 230kV 3 PH 9 Moon Lake 230kV: JXXXX, J8762


Moon Lake - Crossroads 230kV

27

Figure 3.14: LVRT Capability of E001 for Fault_1-LVRT

28


29


30

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 of this analysis is to evaluate the impact of the proposed E001 project on fault duties at substations in the electrical vicinity of the proposed wind farm. Breaker fault duties were computed 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 breakers at substations in the local vicinity indicates that there is adequate interrupting capability following 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 simulated to determine the impact of E001 on the stability and transient voltage recovery of the local Entergy System. Two (2) three-phase stuck-breaker faults at the Moon Lake 230 kV bus were found to be unstable in the pre-project case (without E001). These faults were marginally stable in the post-project case (with E001), but transient voltage violations were observed. Based on these results, it can be concluded that E001 does not further degrade system stability for these faults. 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 was concluded that the instability is not attributable to E001. The system was stable following all other simulated normally-cleared three-phase faults and three-phase stuck-breaker faults. Three-phase stuck breaker faults that exhibited stability or transient voltage violations, as described in the preceding paragraphs, were re-simulated as corresponding single-line-to-ground (SLG) stuck-breaker faults. Results show no stability and transient voltage criteria violations for these faults. The proposed project (E001) complies with FERC Order 661-A on low voltage ride through for wind farms. Results show that the proposed wind farm does not trip off-line by voltage relay actuation for local faults at the POI. Based on the results of the above study, it can be concluded that the proposed E001 wind farm does 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 of conducting the study. If any of the data and/or assumptions made in developing the study model change, the results provided in this report may not apply.

31

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



32

ABB

APPENDIX A Data Provided by Customer

33

ABB

34

ABB

35

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

36

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

37

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

38

ABB

APPENDIX C Plots for Stability Simulations

39

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: [ANGL, RITCHIE U2, 337125]250.00 0.0

CHNL# 66: [ANGL, CROSSROADS U1, 337103]250.00 0.0


CHNL# 65: [ANGL, CLARKSDALE, 337098]250.00 0.0

CHNL# 111: [ANGL, LS POWER, 338401]250.00 0.0


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

WED, SEP 25 2013 14:04

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]250.00 0.0

CHNL# 499: [ANGLE - 1S HAVEN T1 18.000]250.00 0.0

CHNL# 502: [ANGLE - 1S HAVEN S1 13.800]250.00 0.0

CHNL# 82: [ANGLE - 1WHT BLUF U2 26.00]250.00 0.0

CHNL# 122: [ANGLE - 1WRIGHTS C1 13.800]250.00 0.0


WED, SEP 25 2013 14:04

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*[POWR BUS 337118 MACH ’1 ’]300.00 0.0

CHNL# 2008: 222.37*[PMEC BUS 337118 MACH ’1 ’]300.00 0.0


WED, SEP 25 2013 14:04

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:04

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


WED, SEP 25 2013 14:04

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


WED, SEP 25 2013 14:04

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


WED, SEP 25 2013 14:04

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


WED, SEP 25 2013 14:04

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


WED, SEP 25 2013 14:04

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


WED, SEP 25 2013 14:04

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:04

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







WED, SEP 25 2013 14:04

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




WED, SEP 25 2013 14:04

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:04

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:04

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








WED, SEP 25 2013 14:04

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







WED, SEP 25 2013 14:04

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







WED, SEP 25 2013 14:04

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








WED, SEP 25 2013 14:04

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








WED, SEP 25 2013 14:04

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

40

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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




WED, SEP 25 2013 14:05

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*[E001 P COMMAND]300.00 0.0

CHNL# 20: 222.37*[E001 Q COMMAND]300.00 0.0


WED, SEP 25 2013 14:05

TIME (SECONDS)


0.0

0.50000

1.0000

1.5000

2.0000

2.5000

3.0000

3.5000

4.0000

4.50005.0000






WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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







WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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








WED, SEP 25 2013 14:05

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

41

ABB

APPENDIX D Short-Circuit Results

42

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-Project Case %Duty DutyAmp

BUS_NO BUS BREAKER RATINGTYPE %Duty Duty(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 71.5 337100 MEPCLKAUTO230.kV @MEPCLKAUT S 35.9 14366.3 40000.0 36.2 14473.1 0.3 106.8 337107 MOONLAKE230.kV J8762-C S 26.5 10588.1 40000.0 28.6 11457.6 2.1 869.5 337107 MOONLAKE230.kV J8766-C S 18.7 7474.5 40000.0 20.2 8096.8 1.5 622.3 337107 MOONLAKE230.kV J8770-C S 26.5 10588.1 40000.0 28.6 11457.6 2.1 869.5 337998 RITCHI 230.kV B4401-C S 43.5 17402.7 40000.0 44.6 17825.6 1.1 422.9 337998 RITCHI 230.kV B4422-TICO T 53.4 20112.4 37653.3 54.0 20331.7 0.6 219.3 337998 RITCHI 230.kV B4430-TIC T 44.2 16630.2 37653.3 44.8 16861.4 0.6 231.2 337998 RITCHI 230.kV B4744-TICO T 53.0 19966.9 37653.3 53.6 20189.3 0.6 222.4 337998 RITCHI 230.kV B5144-TICO T 47.8 18013.9 37653.3 48.4 18240.4 0.6 226.5 337998 RITCHI 230.kV B8044-TICO T 53.4 20112.4 37653.3 54.0 20331.7 0.6 219.3 337998 RITCHI 230.kV B9721-TICO T 56.4 21252.8 37653.3 57.3 21559.7 0.9 306.9 337998 RITCHI 230.kV B9722-TICO T 43.9 16527.8 37653.3 45.3 17040.9 1.4 513.1 337160 TUNICA230.kV J2704-CO S 23.5 9414.4 40000 23.7 9468.2 0.2 53.8 337160 TUNICA230.kV J2712-CO S 16.7 6686.6 40000 16.9 6747.4 0.2 60.8

43

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-Project Case %Duty DutyAmp

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 71.2 337123 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 0.3 106.8 337107 MOONLAKE230.kV J8762-C S 26.5 10588.1 40000.0 28.6 11457.6 2.1 869.5 337107 MOONLAKE230.kV J8766-C S 18.7 7474.5 40000.0 20.2 8096.8 1.5 622.3 337107 MOONLAKE230.kV J8770-C S 26.5 10588.1 40000.0 28.6 11457.6 2.1 869.5 337998 RITCHI 230.kV B4401-C S 43.5 17402.7 40000.0 44.6 17825.6 1.1 422.9 337998 RITCHI 230.kV B4422-TICO T 53.4 20112.4 37653.3 54.0 20331.7 0.6 219.3 337998 RITCHI 230.kV B4430-TIC T 44.2 16630.2 37653.3 44.8 16861.4 0.6 231.2 337998 RITCHI 230.kV B4744-TICO T 53.0 19966.9 37653.3 53.6 20189.3 0.6 222.4 337998 RITCHI 230.kV B5144-TICO T 47.8 18013.9 37653.3 48.4 18240.4 0.6 226.5 337998 RITCHI 230.kV B8044-TICO T 53.4 20112.4 37653.3 54.0 20331.7 0.6 219.3 337998 RITCHI 230.kV B9721-TICO T 56.4 21252.8 37653.3 57.3 21559.7 0.9 306.9 337998 RITCHI 230.kV B9722-TICO T 43.9 16527.8 37653.3 45.3 17040.9 1.4 513.1 337160 TUNICA230.kV J2704-CO S 23.5 9414.4 40000.0 23.7 9468.2 0.2 53.8 337160 TUNICA230.kV J2712-CO S 16.7 6686.6 40000.0 16.9 6747.4 0.2 60.8

system impact study for e001 - · pdf fileiv the system was stable following all other...

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