Atch_9_-_EasyPower_Model_14Mar18.pdf

PP:MCB-2A 0.4

8 k

V

PP:MCB-2B 0.4

8 k

V T1002B-L 0.4

8 k V

T1002A-L 0.4 8 k

V

T7-L 0.2 08 k

V

T8-L 0.2 08 k

V

T1076-4160 4.1 6 k

V

T1076-L 4.1 6 k

V

89-3 (LINE 1) 4.1

6 k

V

89-3 (LINE 2) 4.1

6 k

V

4160V BUS A (IN) 4.1

6 k

V

4160V BUS B (IN) 4.1

6 k

V

4160V BUS B 4.1

6 k

V

4160V BUS A 4.1

6 k

V

T1003A-L0.4 8 k

V

T1003A CH 0.4

8 k

V

PP:CH1 0.4

8 k

V

T1003B CH 0.4

8 k

V

T1003B-L 0.4 8 k

V

PP:CH2 0.4

8 k

V

T1003A T1003B

TWP-2

30 HP

Induction

16.7%

TWP-1

30 HP

Induction

16.7%

PP CH1

370 HP

Induction

16.7%

PP CH2

370 HP

Induction

16.7%

T1003B-L 1300 Amps

T1003A-L 100 Amps

T1002B-L

5 Amps

T1002A-L 5 Amps

T7-L

75 kVA

T8-L 0 kVA

T1002A

750 kVA

4.16 - 0.48 kV

5.99%

T1002B

750 kVA

4.16 - 0.48 kV

5.95%

T7

300 kVA

4.16 - 0.208 kV

5.04%

T8

300 kVA

4.16 - 0.208 kV

5.12%

T1077

5000 kVA

60 - 4.16 kV

8.1%

400A T1076

5000 kVA

60 - 4.16 kV

8.28%

400A

T1003A

2500 kVA

4.16 - 0.48 kV

5.54%

T1003B

2500 kVA

4.16 - 0.48 kV

5.57%

-1

/C -5 k c m il

C U

[C o n d u it

-1

/C -5 k c m il

C U

[C o n d u it

-1

/C -4

A W

G

C U

[C o n d u it

-1

/C -4

A W

G

C U

[C o n d u it

-1

/C -4

/0 A

W G

C U

[C o n d u it

-1

/C -4

/0 A

W G

C U

[C o n d u it

-1

/C -5 k c m il

C U

[C o n d u it

-1

/C -5 k c m il

C U

[C o n d u it

-1

/C -7 k c m il

C U

[C o n d u it

-1

/C -7 k c m il

C U

[C o n d u it

-1

/C -7 k c m il

C U

[C o n d u it

-1

/C -7 k c m il

C U

[C o n d u it

-1

/C -5 k c m il

C U

[C o n d u it

-1

/C -3 k c m il

C U

[C o n d u it

3-3/C-500 kcmil

CU, 130', [Conduit] 3-1/C-500 kcmil

CU, 30', [Conduit]

3-3/C-500 kcmil

CU, 130', [Conduit]

3-1/C-500 kcmil

CU, 30', [Conduit]

-1

/C -2 k c m il

C U

[C o n d u it

1-1/C-2 AWG

CU, 230', [Conduit]

-1

/C -2 k c m il

C U

[C o n d u it

1-1/C-2 AWG

CU, 230', [Conduit]

-1

/C -5 k c m il

C U

[C o n d u it

2-1/C-300 kcmil

CU, 35', [Conduit]

2-1/C-300 kcmil

CU, 45', [Conduit]

-1

/C -3 k c m il

C U

[C o n d u it

A

G e n e ri c

C U

A

G e n e ri c

C U

A

G e n e ri c

C U

A

G e n e ri c

C U

A

G e n e ri c

C U

A

G e n e ri c

C U

2000A-(Generic)

CU, 15'

2000A-(Generic)

CU, 15'

A

G e n e ri c

C U

4000A-(Generic)

CU, 10'

4000A-(Generic)

CU, 10'

BBC 5-AK-250

2000A

A-C MA-250-C

2000A

OPEN Siemens MA-250

2000A

OPEN Siemens MA-250

2000A

Siemens MA-250

2000A

Siemens MA-250

2000A

Siemens MA-250

2000A

Siemens MA-250

1200A

Siemens MA-250

1200A

Siemens MA-250

2000A

OPEN Siemens MA-250

1200A

OPEN Siemens MA-250

1200A

OPEN

GE AK-75

3000/3300

SQD DS-416

1600/1200

OPENSQD DS-416

1600/1200

SQD DS-416

1600/900

GE AKR-100

4000/4400

SQD RJ

3000/1200

SQD MH

800/700

OPENSQD RJ

3000/1200

OPEN

SQD MH

800/700

GE AK-100

4000/4400

SQD MH

800/700

OPENSQD MH

800/700

Generic 1200A

700A

OPEN Generic 1200A

700A

AS-60-8

Generic 600A LoadBrk

600A

AS-60-9

Generic 600A LoadBrk

600A

AS-60-8A

Generic 600A LoadBrk

600A

89-3 (LINE 1)

Generic 1200A

1200A

89-3 (LINE 2)

Generic 1200A

1200A

OPEN Shawmut A50QS

Shawmut A50QS

Shawmut CL-14

100E

OPEN Shawmut CL-14

100E

S&C SMD-2B

80E

S&C SMD-2B

80E

1000/51000/5

1000/5 1000/5

800/5 200/5 100/5800/5200/5100/5

5151N

51N51N

5151N

51N

51N

51N

51N

51N

51N

T1002A and T1002B primarily supply the standby generator support systems. Since these are off during normal operation, a minimal load was assumed to exist on these two transformers.

All secondary breakers interlocked in SATCOM facility - no access.

Meters for T7 were inoperable.

Loading was assumed for this facility.

Generator

Support

SATCOM

Facility Support

PAVEPAWS

Substation

Old Filter Room

Circuit Loads:

P1: 225 A

P2: 0 A

Smartville-Nicolaus

Line 1

Smartville-Nicolaus

Line 2

Beale Air Force Base

PAVE PAWS Switchgear Replacement

Project BAEY 06-0023

Report No. EE-11-263 First Draft – June 2011

Prepared by:

Edan Engineering Corporation 900 Washington St., Suite 830 Vancouver, Washington 98660

(360) 750-4842 ii

EXECUTIVE SUMMARY

To be included with the final report.

This is the first draft of this study. A revised draft will be issued after inspection of the switchgear.

iii

CONTENTS

1 Introduction ...................................................................................................................... 1-1

1.1 Project Summary ........................................................................................... 1-1

1.2 Analysis Approach ......................................................................................... 1-1

1.2.1 Basis for Analysis ................................................................................... 1-1

1.2.2 EasyPower Model ................................................................................... 1-1

2 Electrical Distribution System Description.................................................................... 2-1

2.1 Utility Distribution ........................................................................................... 2-1

2.1.1 Utility Distribution System ....................................................................... 2-1

2.1.2 Available Short Circuit Current ................................................................ 2-2

2.1.3 PAVE PAWS Substation Protective Relay Settings ................................ 2-3

2.2 PAVE PAWS Switchgear ............................................................................... 2-3

3 Short Circuit Analysis ...................................................................................................... 3-1

3.1 Purpose of Short Circuit Analysis ................................................................... 3-1

3.2 Modeling Considerations ............................................................................... 3-2

3.2.1 Utility Fault Contribution .......................................................................... 3-2

3.2.2 Pre-Fault Voltage .................................................................................... 3-3

3.2.3 Transformers .......................................................................................... 3-3

3.2.4 Generators .............................................................................................. 3-4

3.2.5 Motors ..................................................................................................... 3-4

3.3 Short Circuit Analysis Results ........................................................................ 3-4

3.4 Equipment Fault Current Duty ........................................................................ 3-5

3.4.1 Analysis Requirements ........................................................................... 3-5

3.4.2 Equipment Duty Violations ...................................................................... 3-5

4 Arc Flash Analysis ........................................................................................................... 4-1

4.1 Purpose of Arc Flash Analysis ....................................................................... 4-1

4.2 Analysis Approach ......................................................................................... 4-2

4.3 Arc Flash Analysis Results ............................................................................. 4-2 iv

5 Electrical Protection and Coordination .......................................................................... 5-1

5.1 Electrical Protection and Coordination Criteria ............................................... 5-1

5.2 Recommended Settings ................................................................................. 5-2

A Facility As-Built Drawings .............................................................................................. A-1

B Design Drawings ............................................................................................................. B-1

C Switchgear Drawing Submittals .................................................................................... C-1

D Short Circuit Analysis Summary Reports ..................................................................... D-1

E Arc Flash Results ............................................................................................................ E-1

F EasyPower Model ............................................................................................................. F-1 v

LIST OF FIGURES

Figure 2-1 PAVE PAWS Substation Overview........................................................................... 2-1

Figure 2-2 PAVE PAWS Substation Simplified One-Line ......................................................... 2-2

Figure 3-1 Symmetrical Current Waveform ................................................................................ 3-2

Figure 3-2 Asymmetrical Current Waveform .............................................................................. 3-2

Figure 5-1 Main Breakers and Upstream Protective Relays ........................................................ 5-4

Figure 5-2 Main Breakers and Cross-Tie Breaker ....................................................................... 5-5

Figure 5-3 Main Breakers, Cross-Tie Breaker, and a Feeder Breaker ......................................... 5-6

Figure 5-4 Feeder Breaker and Panels DP1 to DP4 ..................................................................... 5-7

Figure 5-5 Feeder Breaker and MCC Fuses ................................................................................ 5-8

Figure 5-6 Feeder Breaker and UPS System Breakers ................................................................ 5-9 vi

LIST OF TABLES

Table 2-1 Short Circuit Current Available from PG&E at Beale Junction .................................. 2-2

Table 2-2 Short Circuit Current Available at the Input of the PAVE PAWS Substation ............ 2-3

Table 2-3 PAVE PAWS Substation Overcurrent Relay Settings ................................................ 2-3

Table 2-4 New Switchgear Configuration ................................................................................... 2-4

Table 3-1 Short Circuit Current Available from PG&E at Beale Junction .................................. 3-3

Table 3-2 Short Circuit Current Available at the Input of the PAVE PAWS Substation ............ 3-3

Table 5-1 Desired Electrical Protection and Coordination Criteria ............................................. 5-1

Table 5-2 Recommended Switchgear Circuit Breaker Settings .................................................. 5-3

Table D-1 Maximum Fault Current Short Circuit Summary – Three Phase Faults ................... D-1

Table D-2 Maximum Fault Current Short Circuit Summary – Single-Line-to-Ground Faults .. D-4

Table D-3 Normal Operation Short Circuit Summary – Three Phase Faults ............................. D-6

Table D-4 Normal Operation Current Short Circuit Summary – Single-Line-to-Ground Faults D-8

Table D-5 Emergency Generator Operation Short Circuit Summary – Three Phase Faults .... D-11

Table D-6 Emergency Generator Operation Short Circuit Summary – Single-Line-to-Ground Faults ................................................................................................................................. D-13

Table E-1 Arc Flash Calculation Output ..................................................................................... E-2

1-1

INTRODUCTION

1.1 Project Summary

This analysis applies specifically to the new switchgear and associated equipment installed as part of this project.

New 480-volt switchgear is installed as a replacement for existing switchgear in the PAVE PAWS low voltage switchgear in Bldg 1003.

1.2 Analysis Approach

1.2.1 Basis for Analysis

The documents used to perform this analysis include the following:

As-Built Drawings produced by Project BAEY060023, dated June 26, 2009. These drawings are provided in Appendix A.

Design drawings E4.1, Replace Switchgear PAVE PAWS Radar, Single Line Diagram New, and E2.1, Replace Switchgear PAVE PAWS Radar, Single Line Diagram Demo. These drawings are provided in Appendix B.

General Electric Switchgear submittal drawings dated May 10, 2011. These drawings are provided in Appendix C.

The analysis is based on the design as presented in the above documents and does not incorporate any field changes or subsequent changes to the design.

1.2.2 EasyPower Model

A base-wide electrical distribution study was completed in 2010. The EasyPower model that was developed for that study was used as the starting point for this evaluation. The portions of the EasyPower model that are unrelated to PAVE PAWS were discarded, leaving only the primary distribution system between the utility supply and PAVE PAWS.

The 2010 EasyPower model was developed for a primary distribution system study and extended only to the service entrance of each facility. The as-built drawings provided in Appendix A was used to continue the model further into the PAVE PAWS electrical distribution system. The EasyPower model was then revised to incorporate the new equipment provided by this project.

Introduction

1-2

EasyPower Version 9.0.3 was used for this study.

2-1

ELECTRICAL DISTRIBUTION SYSTEM DESCRIPTION

Section 2 provides an overview of the PAVE PAWS electrical distribution system. This information forms the basis for the overall layout of the system model.

2.1 Utility Distribution

2.1.1 Utility Distribution System

PG&E supplies power to Beale AFB via two 60kV transmission lines originating from the WAPA generation network. Beale AFB has five substations on base – Grass Valley, Vasser Lake, B-Street, Doolittle, and PAVE PAWS. The substation at PAVE PAWS is the only 60kV substation dedicated to one facility.

The PAVE PAWS substation contains two substation transformers with individual, manually-operated upstream switches and fusing. Each substation transformer is supplied from a separate 60kV incoming supply line (Smartville-Nicolaus Lines 1 and 2). Figure 2-1 shows the PAVE PAWS substation and Figure 2-2 provides a simplified one-line diagram of the substation.

Figure 2-1

PAVE PAWS Substation Overview

Electrical Distribution System Description

2-2

Smartville- Nicolaus Line 2

T1077

ONAN/ONAF

5000kVA 60kV - 4.16kV 8.1%

T1076

ONAN/ONAF

5000kVA 60 kV - 4.16 kV 8.28%

T1076

MAIN

C irc ui t B

3-

M

C M

C U

#2 C

U

PavePAWS

T1077

MAIN

80E80E

AS-60-9 AS-60-8A

Smartville- Nicolaus Line 1

AS-60-8

B11 A11 N.O.

52 5252 52

52B25252 B10 N.O.

B3 N.O.

52A105252A2 A3

C irc ui t A

3-

M

C M

C U

B1 N.O.

A1

M C

M

3-

M

C M

3-

M

C M

M C

M

#2 C

U

Indoor 4160V Switchgear

Figure 2-2

PAVE PAWS Substation Simplified One-Line

2.1.2 Available Short Circuit Current

The 2010 EasyPower model was used to obtain the available system short circuit current. Table 2-1 provides the short circuit current available from PG&E. Table 2-2 provides the available short circuit current at the input of the PAVE PAWS substation.

Table 2-1

Short Circuit Current Available from PG&E at Beale Junction

Incoming Line 3-Phase Fault

Current (kA) X/R Ratio

SLG Fault

Current (kA) X/R Ratio

Smartville-Nicolaus Line 1 3.5231 2.3603 2.3109 2.232

Smartville-Nicolaus Line 2 4.3737 1.9401 2.9978 1.7464

2-3

Table 2-2

Short Circuit Current Available at the Input of the PAVE PAWS Substation

Incoming Line 3-Phase Fault

Current (kA) X/R Ratio

SLG Fault

Current (kA) X/R Ratio

Smartville-Nicolaus Line 1 2.959 2.05 1.896 2.24

Smartville-Nicolaus Line 2 3.506 1.70 2.328 1.85

2.1.3 PAVE PAWS Substation Protective Relay Settings

CEMIRT from Travis AFB recently reset the substation relays in accordance with the 2010 power system study. The new settings are shown below.

Table 2-3

PAVE PAWS Substation Overcurrent Relay Settings

Relay Settings T1076

Main

T1077

Main

Mains

(A)

Mains

(B) A2 A3 A10 B2 B3 B10

Phase Settings

Manufacturer GE GE Basler Basler Basler Basler GE Basler Basler GE

Type IAC 53 IFC 53

BE1-

BE1-

BE1-

BE1-

IFC

BE1-

BE1-

IFC

Time OC pickup (tap) 4 4 3.5 3.5 3 8 6 3 8 6

Time dial (multiplier) 4.5 4.5 30 30 15 4 5 15 4 5

Instantaneous pickup 60 50 N/A N/A 13 10 150 13 10 150

CT ratio 1000:5 1000:5 1000:5 1000:5 800:5 200:5 100:5 800:5 200:5 100:5

Neutral Settings

Manufacturer GE GE Basler Basler Basler Basler GE Basler Basler GE

Type IAC 53 IFC 53

BE1-

51A

BE1-

BE1-

51A

BE1-

51A

IFC

BE1-

51A

BE1-

51A

IFC

Time OC pickup (tap) 1 1 0.5 1 0.5 1 1.5 0.5 1 1

Time dial (multiplier) 3 3 2.5 0.5 1 1 1.5 1 1 0.5

Instantaneous pickup 12 11 N/A N/A N/A N/A N/A N/A N/A N/A

CT ratio 1000:5 1000:5 1000:5 1000:5 800:5 200:5 100:5 800:5 200:5 100:5

2.2 PAVE PAWS Switchgear

The new switchgear design is provided in Appendix B and the latest switchgear submittal is provided in Appendix C. The following summarizes key design features:

2-4

GE AKD-10 switchgear configured with WavePro low voltage power circuit breakers are provided.

The switchgear and circuit breakers are rated for 85 kA short circuit current.

The main and tie breakers are rated for 4000 amperes; the feeder breakers are rated for 800 amperes.

Conductor sizes are shown on the drawings provided in Appendix C.

The low voltage power trip units are EntelliGuard TU electronic trip units.

The upstream transformers are not replaced by this project.

Table 2-4 provides information regarding the switchgear circuit breakers.

Table 2-4

New Switchgear Configuration

Section and

Compartment Circuit

Sensor

Device Rating

Plug

Rating

102B Main B 4000 4000

102D Fire pump 800 800

103A Panel DP1 800 800

103B Panel DP2 800 800

103C Panel DP3 800 800

103D Panel DP4 800 800

104B Tie Breaker 4000 3600

105A Panel DSA10 800 800

105B Panel DSA11 800 800

105C Panel DSA12 800 800

106A Panel DP9 800 800

106B MCC 2A 800 800

106C MCC 2B 800 800

106D Spare 800 800

107B Main A 4000 4000

107D Spare 800 800

3-1

SHORT CIRCUIT ANALYSIS

3.1 Purpose of Short Circuit Analysis

A short circuit study is an integral and necessary part of selecting and sizing electrical distribution components. Even the best and most reliable electrical distribution system is not immune to occasional short circuits. The objectives of the short circuit analysis include:

Determine short circuit current levels throughout the system.

Confirm that system overcurrent protective device interrupting ratings are not exceeded.

Establish fault current levels for use in the coordination study.

Identify system lineups or configurations that result in unacceptably high levels of fault current.

This section provides a summary of the EasyPower short circuit analysis. Short circuit levels are provided for key locations throughout the electrical distribution system affected by this project.

Equipment duty evaluation results are provided for major equipment and any components that are over duty, i.e., operating beyond its short circuit rating. Appendix C contains short circuit summary reports for the entire system, including:

Three-phase fault levels.

Single-line-to-ground fault levels.

Additional fault types can also be viewed in EasyPower.

Different types of faults produce different levels of short circuit current. The most common type of fault considered is a three-phase bolted fault. A three-phase bolted fault generally bounds other types of faults in terms of maximum fault current. Line to ground fault current levels are also important to determine. In some cases, ground fault current can be higher than the three-phase bolted fault current. Additionally, ground fault current levels are important for evaluating coordination of ground fault protective devices.

When a short circuit occurs in an AC power system, the actual fault current magnitude changes over the first several cycles. The change is due to 1) the decaying contribution of motors and generators, and 2) a phenomenon known as DC offset. DC offset causes the symmetrical current waveform to shift above the zero-axis, producing an asymmetrical waveform – refer to Figure 3-1 and Figure 3-2. This effect decays away exponentially; however, it has the effect of

Short Circuit Analysis

3-2 increasing the peak fault current seen by system equipment. All of these factors are considered in determining equipment short circuit ratings. The practical consequence of decaying fault current levels is that the highest current to which the equipment is exposed occurs within about the first ½ cycle. This fault current quantity is called the Momentary fault current.

Zero Axis

Figure 3-1

Symmetrical Current Waveform

Zero Axis

Figure 3-2

Asymmetrical Current Waveform

The most commonly used fault current quantities are momentary symmetrical and asymmetrical fault current for three phase and ground faults. Because of the importance of asymmetrical fault current values to the overall analysis, it is generally advisable to set the EasyPower display parameters to show both symmetrical and asymmetrical fault current at each bus.

3.2 Modeling Considerations

Note: This project does not change the available short circuit current within the facility. New switchgear, properly rated for the available short circuit current, is installed. The following sections discuss how the short circuit current was modeled within the facility.

3.2.1 Utility Fault Contribution

The 2010 EasyPower model was used to obtain the available system short circuit current. Table 3-1 provides the short circuit current available from PG&E. Table 3-2 provides the available short circuit current at the input of the PAVE PAWS substation.

3-3

Table 3-1

Short Circuit Current Available from PG&E at Beale Junction

Incoming Line 3-Phase Fault

Current (kA) X/R Ratio

SLG Fault

Current (kA) X/R Ratio

Smartville-Nicolaus Line 1 3.5231 2.3603 2.3109 2.232

Smartville-Nicolaus Line 2 4.3737 1.9401 2.9978 1.7464

Table 3-2

Short Circuit Current Available at the Input of the PAVE PAWS Substation

Incoming Line 3-Phase Fault

Current (kA) X/R Ratio

SLG Fault

Current (kA) X/R Ratio

Smartville-Nicolaus Line 1 2.959 2.05 1.896 2.24

Smartville-Nicolaus Line 2 3.506 1.70 2.328 1.85

The above information forms the basis for short circuit currents at the PAVE PAWS facility.

Because of the relatively small motor load in the Base, the short circuit current anywhere in the electrical distribution system is dominated by the utility source.

3.2.2 Pre-Fault Voltage

Pre-fault voltage affects the short circuit results, with a higher pre-fault voltage providing an incrementally higher fault current. The pre-fault voltage for the short circuit study has been increased to 1.02 per unit to account for potentially higher normal operating voltages.

3.2.3 Transformers

Although transformers are not a source of short circuit current, their kVA rating and impedance have a significant effect on the fault current available at the secondary. Fault current magnitudes are very sensitive to transformer ratings and relatively insensitive to the available fault current at the transformer primary. For example, a decrease in the transformer impedance from 4 percent to 2 percent might result in a 75 percent increase in transformer secondary fault current, yet doubling the available fault current supplied by the utility might result in only a 4 percent increase in transformer secondary fault current.

Because of the impact that transformers have on the short circuit analysis results, nameplate data have been used to model the transformers. The conductors on the secondary side of the transformer have been included in the model to ensure accurate short circuit predictions at the service entrance panel.

3-4

3.2.4 Generators

Four 1,875 kVA emergency generators are installed. Each generator is standby rated for 1,875 kVA, 1,500 kW, and 4.16 kV. A 24 ohm neutral ground resistor, rated for 100 amperes for 10 seconds, is installed on each generator.

3.2.5 Motors

Motors contribute to a short circuit. This study was performed with the largest identified motors running.

Smaller motors have a negligible effect on short circuit currents in the primary distribution system and have been neglected. Applying a pre-fault voltage of 1.02 per unit ensures that any contribution of these negligible motors has been bounded.

3.3 Short Circuit Analysis Results

The fault current available within the facility is well within the interrupting rating of the new system equipment. The configuration with the highest short circuit current is for an abnormal case as follows:

Commercial power operating normally.

Two diesel generators operating in parallel with commercial power on each bus.

All modeled motors running.

A second configuration, consisting of normal operation on normal commercial power, was completed as follows:

Commercial power operating normally.

Diesel generators in standby.

Some modeled motors running.

A third configuration, consisting of operation on standby generators, was completed as follows:

Commercial power off.

Two diesel generators operating in parallel with commercial power on each bus.

Some modeled motors running.

The National Electrical Code (NEC), Article 110-24, requires labeling of certain electrical equipment to show the calculated maximum available short circuit current:

3-5

110.24 Available Fault Current.

(A) Field Marking. Service equipment in other than dwelling units shall be legibly marked in the field with the maximum available fault current. The field marking(s) shall include the date the fault current calculation was performed and be of sufficient durability to withstand the environment involved.

(B) Modifications. When modifications to the electrical installation occur that affect the maximum available fault current at the service, the maximum available fault current shall be verified or recalculated as necessary to ensure the service equipment ratings are sufficient for the maximum available fault current at the line terminals of the equipment. The required field marking(s) in 110.24(A) shall be adjusted to reflect the new level of maximum available fault current

The short circuit results provided in this report allow compliance with this requirement.

The EasyPower model has been provided separately, with the name PAVE PAWS [Rev A].dez.

The short circuit results are best viewed in EasyPower. A tabular printout is provided in Appendix C and a one-line diagram has been provided in Appendix E.

3.4 Equipment Fault Current Duty

3.4.1 Analysis Requirements

The consequences of applying electrical equipment, particularly circuit breakers, beyond their rating can have dramatic consequences, including catastrophic failure, fire, and explosion. An unsafe condition might go undetected for years, or even decades, until the system experiences a heavy fault. Then, upon being subjected to a fault current beyond its rating, the device fails. In many instances such failures result in significant damage, prolonged outages, fires, and personnel injury or death. For this reason, all applicable governing codes and standards (NEC, ANSI, NFPA, IEEE, NEMA, and UL) clearly specify that equipment must be applied within its short circuit ratings. Circuit breakers are the focus of attention from a code compliance point of view because they are the devices counted upon to quickly isolate damaging faults.

NEC Article 110-9, establishes the interrupting rating criterion for electrical protection as follows:

110-9. Interrupting Rating. Equipment intended to interrupt current at fault levels shall have an interrupting rating sufficient for the nominal circuit voltage and the current that is available at the line terminals of the equipment.

3.4.2 Equipment Duty Violations

New equipment installed by this project is adequately rated for the available short circuit current.

4-1

ARC FLASH ANALYSIS

Section 4 provides a summary of the EasyPower arc flash analysis results.

4.1 Purpose of Arc Flash Analysis

The nature of arcing equipment failures and the rate of serious burn injuries in the electrical industry led the NFPA to develop arc flash electrical safety guidelines in NFPA 70E, Electrical Safety in the Workplace, for work on or near energized electrical equipment. IEEE 1584, IEEE Guide for Performing Arc-Flash Hazard Calculations, was issued in 2002 to provide an empirically-derived calculation methodology and associated equations for determining arc flash energies at a fault location. Together, these industry standard documents provide guidance regarding how to assess arc flash hazards and add a new dimension to traditional electrical power analysis.

For the Air Force, additional criteria related to arc flash hazards are provided in the following documents:

AFI 32-1064, Electrical Safe Practices.

UFC 3-560-01, Electrical Safety, O&M.

An arc flash analysis typically accomplishes the following:

Calculates arc flash incident energy levels at key locations throughout the system.

Determines the personal protective equipment (PPE) requirements based on arc flash analysis results for specific work locations.

Identifies potential equipment line-ups or protective device setting changes that can reduce the arc flash hazard at specific locations.

Identifies locations in which energized work cannot be conducted safely regardless of available PPE due to exceptionally high arc flash energy levels.

The end purpose of conducting an arc flash analysis is to define the arc flash hazard associated with energized electrical work so that workers can select and wear the appropriate PPE for the anticipated energized work hazard. PPE categories are specified in NFPA 70E.

Arc Flash Analysis

4-2

4.2 Analysis Approach

The short circuit analysis was based on three different possible configurations:

Maximum available fault current – commercial power with all motors and generators operating.

Normal operation – commercial power with generators in standby and some motors operating.

Generator operation – commercial power off with generators running and some motors operating.

Arc flash analyses are based on a specific operating configuration and the results can vary widely in this case. The evaluated configuration is based on normal operation because this is the only configuration for which energized electrical work should ever be authorized.

4.3 Arc Flash Analysis Results

An arc flash summary is provided in Appendix E for the portion of the electrical system affected by this project.

The arc flash protective clothing requirements for energized work is mostly Category #0 and Category #1 throughout the system. The arc flash protective clothing requirements at the new switchgear are Category 3; this higher number is because of the deliberate coordination time delay for the main breakers. If performing energized electrical work downstream of the main breakers, their instantaneous trip can be reactivated to provide a faster response.

5-1

ELECTRICAL PROTECTION AND COORDINATION

Section 5 provides the recommended settings for the new switchgear circuit breakers.

5.1 Electrical Protection and Coordination Criteria

Electrical coordination was evaluated using standard industry methods and criteria. Time-current coordination plots were developed for the system. The time-current curves for related devices are graphically depicted on a common plot. The curves are then compared using the specified criteria to confirm that the nearest protective device upstream from the fault will open before other upstream devices. This comparison is made over the entire possible fault current range. The postulated fault current ranges from a very light overload at the low end up to the maximum predicted fault current for the fault location (based on short circuit analysis values).

The maximum predicted fault current represents the worst-case 3-phase momentary asymmetrical fault current (line faults) or worst-case line-to-ground momentary asymmetrical fault current (ground faults). Table 5-1 provides the criteria applied in this evaluation.

Table 5-1

Desired Electrical Protection and Coordination Criteria

Upstream

Device

Downstream

Device Criteria

TOC Relay or Recloser

TOC Relay A minimum margin of 0.4 seconds between TC curves in the TOC region. No overlap between the TC curves for instantaneous elements with 10% margin.

TOC Relay or Recloser

Switchgear Breaker, Fuse, and MCCB

A minimum margin of 0.3 seconds between the TC curve and the switchgear breaker/MCCB/fuse curve in the TOC region. No overlap between the TC curves for instantaneous elements with 10% margin.

Switchgear Breaker

Switchgear Breaker

No overlap between TC curves. All tolerances are accounted for in the curves.

Switchgear Breaker

MCCB No overlap between TC curves. All tolerances are accounted for in the curves.

MCCB MCCB No overlap between TC curves. All tolerances are accounted for in the curves.

MCCB Fuse (Non-Current Limiting)

Total clearing time of fuse must be below the minimum trip time of breaker in the TOC region. Alternatively, the fuse average clearing time must be below the minimum trip time of breaker with 10% margin. Maximum fault current sensed by MCCB must be limited to below the MCCB instantaneous pickup.

Electrical Protection and Coordination

5-2

Upstream

Device

Downstream

Device Criteria

MCCB Fuse (Current Limiting)

Total clearing time of fuse must be below the minimum trip time of breaker in the TOC region. Alternatively, the fuse average clearing time must be below the minimum trip time of the breaker with 10% margin. Peak let-through current of fuse must be below the MCCB instantaneous pickup.

Fuse Fuse Total clearing time of downstream fuse must be below the minimum melt time of upstream fuse. Alternatively, the average clearing times of the fuses must not overlap with a 10% margin applied to each fuse. Alternatively, the I2t of the downstream fuse must be lower than the I2t of the upstream fuse. The I2t requirement is considered satisfied if fuse manufacturer’s selectivity ratio is maintained.

Fuse MCCB No overlap between MCCB TC curve and minimum melt time curve for fuse. Alternatively, no overlap between MCCB TC curve and average clearing time curve for fuse with 10% margin. No coordination above intersection of fuse TC curve and MCCB instantaneous curve.

Transformers Protective device must clear the fault before the transformer damage curve is exceeded. Conservatively use frequent fault damage curves.

Upstream protective device setting must allow for transformer inrush without nuisance trip.

Cables Protective device must clear the fault before cable I2t damage curve is exceed.

5.2 Recommended Settings

The new switchgear uses GE WavePro circuit breakers and the low voltage power trip units are EntelliGuard TU electronic trip units. EasyPower contains this equipment in its standard library.

Table 5-2 provides the recommended settings for the circuit breakers in this switchgear.

Subsequent figures show the effect of these settings.

5-3

Table 5-2

Recommended Switchgear Circuit Breaker Settings

Section and

Compartment Circuit

Sensor

Device

Rating

Plug

Rating

Long Time

Pickup

Long Time

Delay

Short

Time

Pickup

Short

Time

Delay

Inst.

Pickup

Ground

Fault

Pickup

Ground

Fault

Delay

102B Main B 4000 4000 0.85 F-4 4.0 8.0 None 0.3 8

102D Fire pump 800 800 1.0 F-14 3.5 11.0 6 None None

103A Panel DP1 800 800 1.0 F-14 3.5 11.0 6 None None

103B Panel DP2 800 800 1.0 F-14 3.5 11.0 6 None None

103C Panel DP3 800 800 1.0 F-14 3.5 11.0 6 None None

103D Panel DP4 800 800 1.0 F-14 3.5 11.0 6 None None

104B Tie Breaker 4000 3600 0.65 F-4 4.0 5.0 None 0.23 5

105A Panel DSA10 800 800 1.0 Max F 8.0 11.0 10 None None

105B Panel DSA11 800 800 1.0 Max F 8.0 11.0 10 None None

105C Panel DSA12 800 800 1.0 Max F 8.0 11.0 10 None None

106A Panel DP9 800 800 1.0 F-14 3.5 11.0 6 None None

106B MCC 2A 800 800 1.0 F-6 3.0 8.0 5 None None

106C MCC 2B 800 800 1.0 F-6 3.0 8.0 5 None None

106D Spare 800 800 — — — — — — —

107B Main A 4000 4000 0.85 F-4 4.0 8.0 None 0.3 8

107D Spare 800 800 — — — — — — —

Notes:

1. Use the Fuse (I^4T) curve for the long time delay setting.

2. Leave spare breakers at the factory default settings.

5-4

Figure 5-1 shows the phase time current curve for the main breaker and upstream equipment.

The selected settings allow the transformer full-load current and also coordinate with its upstream protective relay.

10000

10000

100000

100000

.01 .01

.02 .02

.03 .03

.04 .04

.05 .05

.07 .07

.1 .1

.2 .2

.3 .3

.4 .4

.5 .5

.7 .7

1 1

2 2

3 3

4 4 5 5

7 7

10 10

20 20

30 30

40 40 50 50

70 70

100 100

200 200

300 300

400 400 500 500

700 700

1000 1000

CURRENT IN AMPERES AT 480 VOLTS

CURRENT IN AMPERES AT 480 VOLTS

T

IM

E

IN

S E

C O

N D

S

T

IM

E

IN

S E

C O

N D

S

T1003-T1 2500 kVA 5.57%

T1003-T1 2500 kVA

INRUSH

T1003-T1

FLA

B1003 BUS B MAIN

GE Entelliguard TU Sensor = 4000 Plug = 4000 Cur Set = 0.85 (3400A) LT Curve = Fuse (I^4T) LT Band = F-4

STPU = 4 (13600A)

ST Delay = 8 ST Delay I²t = Out

B1003 BUS B MAIN

39987A

52-A2-50/51 Basler BE1-51 51/50 B6 Very Inv CT Ratio = 800/5 Tap = 3 (480A) Time Dial = 15 Instantaneous = 13 (6240A)

52-A2-50/51

52-A2-50/51 7069A

Figure 5-1

Main Breakers and Upstream Protective Relays

5-5

Figure 5-2 shows the time current curves for the main breakers and the cross-tie breaker. During periods when the cross-tie breaker is closed, any system fault should trip the cross-tie breaker before the main breaker for faults downstream of the cross-tie breaker.

10000

10000

100000

100000

.01 .01

.02 .02

.03 .03

.04 .04

.05 .05

.07 .07

.1 .1

.2 .2

.3 .3

.4 .4

.5 .5

.7 .7

1 1

2 2

3 3

4 4 5 5

7 7

10 10

20 20

30 30

40 40 50 50

70 70

100 100

200 200

300 300

400 400 500 500

700 700

1000 1000

CURRENT IN AMPERES AT 480 VOLTS

CURRENT IN AMPERES AT 480 VOLTS

T

IM

E

IN

S E

C O

N D

S

T

IM

E

IN

S E

C O

N D

S

B1003 BUS TIE

GE Entelliguard TU Sensor = 4000 Plug = 3600 Cur Set = 0.65 (2340A) LT Curve = Fuse (I^4T) LT Band = F-4

STPU = 4 (9360A)

ST Delay = 5 ST Delay I²t = Out

B1003 BUS TIE

43057A

B1003 BUS B MAIN

GE Entelliguard TU Sensor = 4000 Plug = 4000 Cur Set = 0.85 (3400A) LT Curve = Fuse (I^4T) LT Band = F-4

STPU = 4 (13600A)

ST Delay = 8 ST Delay I²t = Out

B1003 BUS TIE - Ground Fault GE Entelliguard TU Sensor = 4000

GFPU = 0.23 (920A)

Delay = 5

B1003 BUS B MAIN - Ground Fault GE Entelliguard TU Sensor = 4000

GFPU = 0.3 (1200A)

Delay = 8

Figure 5-2

Main Breakers and Cross-Tie Breaker

5-6

Figure 5-3 shows the typical coordination between the main (and cross-tie) breakers with a feeder breaker. The instantaneous trip has been disabled for the main (and cross-tie) breakers and is active for the feeder breakers to ensure electrical coordination.

10000

10000

100000

100000

.01 .01

.02 .02

.03 .03

.04 .04

.05 .05

.07 .07

.1 .1

.2 .2

.3 .3

.4 .4

.5 .5

.7 .7

1 1

2 2

3 3

4 4 5 5

7 7

10 10

20 20

30 30

40 40 50 50

70 70

100 100

200 200

300 300

400 400 500 500

700 700

1000 1000

CURRENT IN AMPERES AT 480 VOLTS

CURRENT IN AMPERES AT 480 VOLTS

T

IM

E

IN

S E

C O

N D

S

T

IM

E

IN

S E

C O

N D

S

B1003 BUS TIE

GE Entelliguard TU Sensor = 4000 Plug = 3600 Cur Set = 0.65 (2340A) LT Curve = Fuse (I^4T) LT Band = F-4

STPU = 4 (9360A)

ST Delay = 5 ST Delay I²t = Out

B1003 BUS TIE

43057A

B1003 BUS B MAIN

GE Entelliguard TU Sensor = 4000 Plug = 4000 Cur Set = 0.85 (3400A) LT Curve = Fuse (I^4T) LT Band = F-4

STPU = 4 (13600A)

ST Delay = 8 ST Delay I²t = Out

B1003 DP-4

GE Entelliguard TU Sensor = 800 Plug = 800 Cur Set = 1 (800A) LT Curve = Fuse (I^4T) LT Band = F-14

STPU = 3.5 (2800A)

ST Delay = 11 ST Delay I²t = Out Inst = 6 (4800A)

B1003 BUS TIE - Ground Fault GE Entelliguard TU Sensor = 4000

GFPU = 0.23 (920A)

Delay = 5

B1003 BUS B MAIN - Ground Fault GE Entelliguard TU Sensor = 4000

GFPU = 0.3 (1200A)

Delay = 8

Figure 5-3

Main Breakers, Cross-Tie Breaker, and a Feeder Breaker

5-7

Figure 5-4 shows the expected electrical coordination between the feeder breakers and downstream radar panels DP1 through DP4. For any fault downstream of panels DP1 through DP4, their fusing should clear the fault.

10000

10000

100000

100000

.01 .01

.02 .02

.03 .03

.04 .04

.05 .05

.07 .07

.1 .1

.2 .2

.3 .3

.4 .4

.5 .5

.7 .7

1 1

2 2

3 3

4 4 5 5

7 7

10 10

20 20

30 30

40 40 50 50

70 70

100 100

200 200

300 300

400 400 500 500

700 700

1000 1000

CURRENT IN AMPERES AT 480 VOLTS

CURRENT IN AMPERES AT 480 VOLTS

T

IM

E

IN

S E

C O

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S

T

IM

E

IN

S E

C O

N D

S

B1003 DP-1

GE Entelliguard TU Sensor = 800 Plug = 800 Cur Set = 1 (800A) LT Curve = Fuse (I^4T) LT Band = F-14

STPU = 3.5 (2800A)

ST Delay = 11 ST Delay I²t = Out Inst = 6 (4800A)

B1003 DP-1

39987A

B1003 DP-1 PP-4

Ferraz Shawmut Amp-Trap

A50QS

Figure 5-4

Feeder Breaker and Panels DP1 to DP4

5-8

Figure 5-5 shows the expected coordination between the feeder breakers and the downstream MCC fusing. The coordination is marginal for the largest fuse size; however, the feeder breaker instantaneous trip cannot be increased without compromising upstream coordination.

10000

10000

100000

100000

.01 .01

.02 .02

.03 .03

.04 .04

.05 .05

.07 .07

.1 .1

.2 .2

.3 .3

.4 .4

.5 .5

.7 .7

1 1

2 2

3 3

4 4 5 5

7 7

10 10

20 20

30 30

40 40 50 50

70 70

100 100

200 200

300 300

400 400 500 500

700 700

1000 1000

CURRENT IN AMPERES AT 480 VOLTS

CURRENT IN AMPERES AT 480 VOLTS

T

IM

E

IN

S E

C O

N D

S

T

IM

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IN

S E

C O

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S

B1003 DP-11

Ferraz Shawmut Amp-Trap

A50QS

B1003 DP-11

41327A

B1003 CT-1

Ferraz Shawmut Amp-Trap

A50QS

B1003 UC-DMTS

Ferraz Shawmut Amp-Trap A50P 20A

B1003 MCC 2B

GE Entelliguard TU Sensor = 800 Plug = 800 Cur Set = 1 (800A) LT Curve = Fuse (I^4T) LT Band = F-6

STPU = 3 (2400A)

ST Delay = 8 ST Delay I²t = Out Inst = 5 (4000A)

Figure 5-5

Feeder Breaker and MCC Fuses

5-9

Figure 5-6 shows the expected coordination between the feeder breakers and the downstream UPS systems. Although the coordination is marginal, the feeder breaker instantaneous trip cannot be increased without compromising upstream coordination.

10000

10000

100000

100000

.01 .01

.02 .02

.03 .03

.04 .04

.05 .05

.07 .07

.1 .1

.2 .2

.3 .3

.4 .4

.5 .5

.7 .7

1 1

2 2

3 3

4 4 5 5

7 7

10 10

20 20

30 30

40 40 50 50

70 70

100 100

200 200

300 300

400 400 500 500

700 700

1000 1000

CURRENT IN AMPERES AT 480 VOLTS

CURRENT IN AMPERES AT 480 VOLTS

T

IM

E

IN

S E

C O

N D

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T

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IN

S E

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DSA-11-1

Cutler Hammer Series C

LD

Frame = 600A(300-600AT) Trip = 600 Inst = 8 (4800A)

B1003 DSA-11

GE Entelliguard TU Sensor = 800 Plug = 800 Cur Set = 1 (800A) LT Curve = Fuse (I^4T) LT Band = Max F

STPU = 8 (6400A)

ST Delay = 11 ST Delay I²t = Out Inst = 10 (8000A)

B1003 DSA-11

43483A

Figure 5-6

Feeder Breaker and UPS System Breakers

A-1

A

FACILITY AS-BUILT DRAWINGS

Appendix A provides the as-built drawings that were used to start the electrical analysis.

Facility As-Built Drawings

A-2

A-3

A-4

A-5

A-6

A-7

A-8

A-9

A-10

A-11

A-12

A-13

A-14

A-15

A-16

A-17

A-18

A-19

B-1

B

DESIGN DRAWINGS

Appendix B provides the design drawings that were provided in support of the electrical analysis.

Design Drawings

B-2

Design Drawings

B-3

C-1

C

SWITCHGEAR DRAWING SUBMITTALS

Appendix C provides the latest switchgear submittal drawings from General Electric.

Switchgear Drawing Submittals

C-2

C-3

C-4

D-1

D

SHORT CIRCUIT ANALYSIS SUMMARY REPORTS

Appendix D provides the short circuit results for different evaluated configurations:

Maximum available fault current – commercial power with all motors and generators operating.

Normal operation – commercial power with generators in standby and some motors operating. Note: some buses will show a zero short circuit current because the motors are off for this evaluated case.

Generator operation – commercial power off with generators running and some motors operating. Note: some buses will show a zero short circuit current because the motors are off for this evaluated case.

Table Refer to Section 3 for a discussion of the short circuit currents.

Table D-1

Maximum Fault Current Short Circuit Summary – Three Phase Faults

Name Bus

Voltage

Symmetrical Fault

Current

X/R Ratio

Multiplication Factor

Asymmetrical Fault Current

B1003 BUS A 480 42238.6 8.04 1.39 58832.1

B1003 BUS B 480 37396.3 7.76 1.38 51761.3

B1003 CT-1 480 15982.0 0.62 1.00 15985.9

B1003 CT-2 480 15982.1 0.62 1.00 15985.9

B1003 DP-1 480 29261.1 4.90 1.26 36992.1

B1003 DP-1 PP-1 480 16147.3 0.96 1.00 16215.8

B1003 DP-1 PP-2 480 18921.0 1.54 1.03 19473.9

B1003 DP-1 PP-3 480 18394.8 1.48 1.03 18872.9

B1003 DP-1 PP-4 480 16518.4 1.31 1.02 16797.1

B1003 DP-1 PP-5 480 16100.5 1.28 1.02 16346.5

B1003 DP-1 PP-6 480 16100.5 1.28 1.02 16346.5

B1003 DP-2 480 25842.1 4.24 1.23 31678.8

Short Circuit Analysis Summary Reports

D-2

Name Bus

Voltage

Symmetrical Fault

Current

X/R Ratio

Multiplication Factor

Asymmetrical Fault Current

B1003 DP-2 PP-7 480 18343.9 1.69 1.04 19064.4

B1003 DP-2 PP-8 480 16955.7 1.52 1.03 17431.7

B1003 DP-2 PP-9 480 16123.5 1.43 1.02 16491.5

B1003 DP-2 PP-10 480 15358.3 1.35 1.02 15646.8

B1003 DP-2 PP-11 480 14998.9 1.32 1.02 15255.5

B1003 DP-2 PP-12 480 14653.9 1.29 1.02 14883.0

B1003 DP-3 480 28028.1 4.64 1.25 35026.5

B1003 DP-3 PP-13 480 15775.3 0.98 1.00 15848.2

B1003 DP-3 PP-14 480 18385.1 1.55 1.03 18935.5

B1003 DP-3 PP-15 480 17889.0 1.49 1.03 18366.7

B1003 DP-3 PP-16 480 16113.0 1.33 1.02 16395.4

B1003 DP-3 PP-17 480 15716.1 1.29 1.02 15966.0

B1003 DP-3 PP-18 480 15716.1 1.29 1.02 15966.0

B1003 DP-4 480 24869.1 4.08 1.22 30240.4

B1003 DP-4 PP-19 480 17837.7 1.70 1.04 18548.5

B1003 DP-4 PP-20 480 16524.4 1.53 1.03 16999.0

B1003 DP-4 PP-21 480 15734.5 1.44 1.02 16103.7

B1003 DP-4 PP-22 480 15006.4 1.36 1.02 15297.5

B1003 DP-4 PP-23 480 14663.9 1.33 1.02 14923.4

B1003 DP-4 PP-24 480 14334.7 1.30 1.02 14566.9

B1003 DP-9 480 35983.4 4.46 1.24 44603.5

B1003 DP-10 480 22462.9 1.90 1.05 23679.9

B1003 DP-11 480 23881.8 2.02 1.06 25389.8

B1003 FP 480 32858.1 5.31 1.29 42240.2

B1003 LP2 480 6389.8 0.33 1.00 6389.8

B1003 LP2 ATS 480 18679.7 0.71 1.00 18692.9

B1003 LP3 480 4609.7 0.28 1.00 4609.7

B1003 LP3 480 14803.6 0.57 1.00 14805.5

B1003 MCC 2A 480 40529.7 6.91 1.35 54912.7

B1003 MCC 2B 480 40529.3 6.91 1.35 54912.0

B1003 RP1 0.208 2474.7 1.26 1.01 2510.9

D-3

Name Bus

Voltage

Symmetrical Fault

Current

X/R Ratio

Multiplication Factor

Asymmetrical Fault Current

B1003 RP2 0.208 4604.2 1.54 1.03 4739.2

B1003 T3 IN 480 13846.0 0.72 1.00 13856.9

B1003 T4 IN 480 6562.8 0.27 1.00 6562.8

B1003 TWP-1 480 16006.1 0.62 1.00 16010.1

B1003 TWP-2 480 16006.1 0.62 1.00 16010.1

B1003 UC-2 480 15937.5 0.61 1.00 15941.1

B1003 UC-DMTS 480 15935.1 0.61 1.00 15938.6

DSA-10 480 32485.2 3.44 1.17 38087.5

DSA-11 480 32639.3 4.07 1.22 39663.5

DSA-12 480 32639.3 4.07 1.22 39663.5

PP:CH1 480 37207.6 4.91 1.26 47063.4

PP:CH2 480 36192.6 4.52 1.24 44986.6

SBM1 480 2205.5 18.71 1.56 3444.6

SBM1 OUTPUT 480 2199.9 17.99 1.56 3422.7

SBM2 480 2205.5 18.71 1.56 3444.6

SBM2 OUTPUT 480 2196.2 17.54 1.55 3408.2

SUPS1 OUT 480 2205.5 18.71 1.56 3444.6

SUPS2 OUT 480 2205.5 18.71 1.56 3444.6

SUPS3 OUT 480 2205.5 18.71 1.56 3444.6

SUPS4 OUT 480 2205.5 18.71 1.56 3444.6

T1003-T1 OUT 480 37511.8 8.02 1.39 52222.2

T1003-T2 OUT 480 42386.1 8.36 1.40 59439.2

T1003A CH 480 41157.0 7.49 1.38 56601.0

T1003B CH 480 35731.5 6.74 1.35 48178.6

D-4

Table D-2

Maximum Fault Current Short Circuit Summary – Single-Line-to-Ground Faults

Name Bus

Voltage

Symmetrical Fault

Current

X/R Ratio

Multiplication Factor

Asymmetrical Fault Current

B1003 BUS A 480 44640.4 4.70 1.25 55936.7

B1003 BUS B 480 40863.4 4.79 1.26 51422.5

B1003 CT-1 480 8825.6 0.38 1.00 8825.6

B1003 CT-2 480 8825.6 0.38 1.00 8825.6

B1003 DP-1 480 25196.5 3.20 1.16 29104.7

B1003 DP-1 PP-1 480 9590.9 0.65 1.00 9594.3

B1003 DP-1 PP-2 480 12255.9 1.07 1.01 12342.3

B1003 DP-1 PP-3 480 11781.5 1.04 1.01 11853.9

B1003 DP-1 PP-4 480 10186.5 0.94 1.00 10225.0

B1003 DP-1 PP-5 480 9850.0 0.92 1.00 9883.5

B1003 DP-1 PP-6 480 9850.0 0.92 1.00 9883.5

B1003 DP-2 480 20446.6 2.90 1.13 23153.3

B1003 DP-2 PP-7 480 11890.4 1.21 1.01 12034.8

B1003 DP-2 PP-8 480 10663.0 1.10 1.01 10750.0

B1003 DP-2 PP-9 480 9967.3 1.05 1.01 10031.4

B1003 DP-2 PP-10 480 9351.8 1.00 1.01 9400.1

B1003 DP-2 PP-11 480 9070.1 0.98 1.00 9112.5

B1003 DP-2 PP-12 480 8804.1 0.96 1.00 8841.4

B1003 DP-3 480 23388.0 3.08 1.15 26804.2

B1003 DP-3 PP-13 480 9351.0 0.67 1.00 9355.3

B1003 DP-3 PP-14 480 11825.2 1.09 1.01 11917.2

B1003 DP-3 PP-15 480 11384.7 1.06 1.01 11462.2

B1003 DP-3 PP-16 480 9893.2 0.96 1.00 9935.1

B1003 DP-3 PP-17 480 9576.6 0.94 1.00 9613.1

B1003 DP-3 PP-18 480 9576.6 0.94 1.00 9613.1

B1003 DP-4 480 19235.2 2.83 1.13 21679.5

B1003 DP-4 PP-19 480 11478.1 1.23 1.01 11627.5

B1003 DP-4 PP-20 480 10334.1 1.12 1.01 10425.4

B1003 DP-4 PP-21 480 9681.5 1.06 1.01 9749.3

D-5

Name Bus

Voltage

Symmetrical Fault

Current

X/R Ratio

Multiplication Factor

Asymmetrical Fault Current

B1003 DP-4 PP-22 480 9101.5 1.02 1.01 9153.0

B1003 DP-4 PP-23 480 8835.3 1.00 1.01 8880.5

B1003 DP-4 PP-24 480 8583.4 0.98 1.00 8623.3

B1003 DP-9 480 32097.7 2.66 1.11 35736.7

B1003 DP-10 480 14890.3 1.33 1.02 15157.2

B1003 DP-11 480 16235.1 1.39 1.02 16572.5

B1003 FP 480 30917.4 3.23 1.16 35786.3

B1003 LP2 480 3278.4 0.24 1.00 3278.4

B1003 LP2 ATS 480 10674.6 0.43 1.00 10674.7

B1003 LP3 480 2343.8 0.22 1.00 2343.8

B1003 LP3 480 8099.0 0.36 1.00 8099.1

B1003 MCC 2A 480 40823.0 4.03 1.21 49518.7

B1003 MCC 2B 480 40822.7 4.03 1.21 49518.3

B1003 RP1 0.208 2710.1 1.35 1.02 2760.4

B1003 RP2 0.208 5048.3 1.59 1.03 5214.0

B1003 T3 IN 480 7675.2 0.51 1.00 7675.6

B1003 T4 IN 480 3356.3 0.19 1.00 3356.3

B1003 TWP-1 480 8831.9 0.38 1.00 8831.9

B1003 TWP-2 480 8831.9 0.38 1.00 8832.0

B1003 UC-2 480 8814.6 0.38 1.00 8814.7

B1003 UC-DMTS 480 8814.0 0.38 1.00 8814.0

DSA-10 480 26582.6 2.13 1.07 28477.0

DSA-11 480 27056.3 2.56 1.11 29914.6

DSA-12 480 27056.3 2.56 1.11 29914.6

PP:CH1 480 35082.5 3.24 1.16 40616.6

PP:CH2 480 33037.9 2.93 1.13 37477.3

SBM1 480 2202.6 18.13 1.56 3429.4

SBM1 OUTPUT 480 2191.5 16.83 1.55 3386.3

SBM2 480 2202.6 18.13 1.56 3429.4

SBM2 OUTPUT 480 2184.2 16.07 1.54 3358.2

SUPS1 OUT 480 2202.6 18.14 1.56 3429.6

D-6

Name Bus

Voltage

Symmetrical Fault

Current

X/R Ratio

Multiplication Factor

Asymmetrical Fault Current

SUPS2 OUT 480 2202.6 18.14 1.56 3429.6

SUPS3 OUT 480 2202.6 18.14 1.56 3429.6

SUPS4 OUT 480 2202.6 18.14 1.56 3429.6

T1003-T1 OUT 480 43635.1 7.88 1.39 60564.2

T1003-T2 OUT 480 47971.6 8.12 1.40 66927.3

T1003A CH 480 44272.8 6.20 1.33 58741.8

T1003B CH 480 39071.2 5.60 1.30 50779.7

Table D-3

Normal Operation Short Circuit Summary – Three Phase Faults

Name Bus

Voltage

Symmetrical Fault

Current

X/R Ratio

Multiplication Factor

Asymmetrical Fault Current

B1003 BUS A 480 31894.0 7.15 1.36 43482.7

B1003 BUS B 480 29469.4 6.97 1.36 39987.5

B1003 CT-1 480 14724.4 0.74 1.00 14737.8

B1003 CT-2 480 0.0 0.00 1.71 0.0

B1003 DP-1 480 24165.7 4.92 1.27 30580.7

B1003 DP-1 PP-1 480 14713.7 1.08 1.01 14826.2

B1003 DP-1 PP-2 480 16778.2 1.70 1.04 17445.4

B1003 DP-1 PP-3 480 16374.4 1.64 1.04 16960.0

B1003 DP-1 PP-4 480 14906.2 1.45 1.02 15265.6

B1003 DP-1 PP-5 480 14573.2 1.41 1.02 14893.7

B1003 DP-1 PP-6 480 14573.2 1.41 1.02 14893.7

B1003 DP-2 480 21787.1 4.35 1.23 26853.0

B1003 DP-2 PP-7 480 16297.4 1.85 1.05 17122.7

B1003 DP-2 PP-8 480 15219.0 1.66 1.04 15787.6

B1003 DP-2 PP-9 480 14561.1 1.56 1.03 15011.3

B1003 DP-2 PP-10 480 13948.3 1.48 1.03 14308.7

B1003 DP-2 PP-11 480 13657.8 1.44 1.02 13981.6

B1003 DP-2 PP-12 480 13377.5 1.41 1.02 13669.0

B1003 DP-3 480 23318.9 4.70 1.25 29224.1

D-7

Name Bus

Voltage

Symmetrical Fault

Current

X/R Ratio

Multiplication Factor

Asymmetrical Fault Current

B1003 DP-3 PP-13 480 14398.3 1.10 1.01 14514.9

B1003 DP-3 PP-14 480 16353.7 1.71 1.04 17012.3

B1003 DP-3 PP-15 480 15970.3 1.65 1.04 16550.3

B1003 DP-3 PP-16 480 14572.7 1.46 1.02 14932.7

B1003 DP-3 PP-17 480 14254.9 1.42 1.02 14576.7

B1003 DP-3 PP-18 480 14254.9 1.42 1.02 14576.7

B1003 DP-4 480 21092.4 4.20 1.22 25810.2

B1003 DP-4 PP-19 480 15895.8 1.86 1.05 16705.6

B1003 DP-4 PP-20 480 14869.2 1.67 1.04 15432.1

B1003 DP-4 PP-21 480 14241.3 1.57 1.03 14689.4

B1003 DP-4 PP-22 480 13655.5 1.49 1.03 14015.9

B1003 DP-4 PP-23 480 13377.5 1.45 1.02 13701.8

B1003 DP-4 PP-24 480 13108.8 1.42 1.02 13401.5

B1003 DP-9 480 28187.1 4.62 1.25 35202.6

B1003 DP-10 480 19256.3 2.12 1.07 20620.5

B1003 DP-11 480 20277.0 2.25 1.08 21926.8

B1003 FP 480 0.0 0.00…