ARC FLASH MITIGATION & DEVICE COORDINATION · PDF filecoordination between upstream and downstream overcurrent ... detailed electrical engineer ing analysis with the ETAP ... ARC FLASH

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PCX Corporation 33 Pony Farm Road Clayton, NC 27520 919-550-2800

1 | P a g e ARC FLASH MITIGATION & DEVICE COORDINATION ANALYSIS

STORE #XXXX – City, State

ARC FLASH MITIGATION & DEVICE COORDINATION ANALYSIS

STORE #XXXX – CITY, STATE

Revision Control

Rev Number Rev Date Description Rev By

0 X-XX-2016 Release XXX

1 X-XX-2016 PE Comment & Review Implementation

XXX & XXX

2 X-XX-2016 FINAL XXX & XXX

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Table of Contents

1. Executive Summary

2. Calculation Objective

3. Calculation Method – Software Used: ETAP Version 12.6.0

4. Protective Device Coordination – Design Basis

5. Short Circuit Study - Design Basis

6. Conclusions – Arc Flash Hazard Analysis

7. References Appendix A ETAP One Line diagram Appendix B INPUT DATA and Assumptions Appendix C Coordination study report – including overcurrent

protective device settings Appendix D Short Circuit results Appendix E Arc Flash results Appendix F Equipment Labels Appendix G Reference Documents

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1 Executive Summary

1.1 Results

An arc-flash hazard mitigation study was completed for Store #XXXX in City, State using the ETAP Electrical Engineering Software Program by PCX Corporation. These are the key findings of this electrical engineering study:

A. Using the methodology prescribed in section 2, Zero (0) equipment buses within the plant were computed with an arc flash hazard incident energy level greater than 40cal/cm2 at recommended settings for the breakers in the system.

B. Two main breakers have setpoints available – Utility and Generator. All Main Switch Board (MSB) settings were analyzed at the recommended settings for the two main breakers for this study.

C. The Main Switchboard MSB (Main Breaker Section) requires to be labeled for the worst case arc flash hazard.

D. 208VAC panels have an energy level 0 arc flash hazard based on GE Spectra series Panelboards and breakers when all CB are set to minimum instantaneous values, with the exception of panel LRX, which has an energy level 1 arc flash hazard.

E. The following 480VAC panel has an energy level 4 arc flash hazard: i. MSB (Main Breaker)

F. Panels CHA1, CHA2, and CHB have been excluded from this study due to lack of field information. G. Refer to Series rating document in appendix G (as required).

1.2 Recommendations After reviewing the results of the Arc-Flash Hazard Analysis, the following actions are recommended:

A. Utility main setpoints should be: i. Long time pickup: 1 (1600A); ii. Long time band: 1 iii. Short time pickup: 4 (6400A) iv. Short time Band: Min (1) v. I2t setpoint: OUT vi. Instantaneous: 3 (4800A) vii. Ground pickup: 0.4 (640A) viii. Ground Band: 1 ix. Ground I2t: OUT

B. Generator main setpoints should be:

i. Long time pickup: FIXED (800A); ii. Long time band: FIXED iii. Short time pickup: FIXED (3940.65A) iv. Short time Band: FIXED v. I2t setpoint: IN vi. Instantaneous: 5 (6305.04A) vii. Ground pickup N/A viii. Ground Band: N/A ix. Ground I2t: N/A

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C. MSB Distribution breakers should have the following instantaneous trip settings: i. H1A: 5 (3162 A) ii. H1P: MIN iii. T1D: MIN iv. DTA: 5 (3528.9 A) v. MTB: MAX vi. AHU1: MAX vii. Baler: MAX viii. Compactor: MAX ix. Sub-Metering: MIN x. Oven (Top): MIN xi. Oven (Bottom): MIN xii. PLM: MIN xiii. UH (Vestibule): MIN xiv. Water Heater: MIN

D. Ensure all other MCB Instantaneous settings are set to MINIMUM ensuring incident energy levels are

between categories 0-1. E. Verify breaker settings on an annual basis to ensure arc flash hazard does not increase for the breakers

identified in Appendix C: coordination study report. F. Install the arc flash hazard study warning labels on applicable equipment throughout the store in

accordance with [2]. Whenever changes are made to the power system, subsequent studies may be required to validate existing settings of devices.

G. Lower all 208VAC transformers to less than 125kva eliminating the requirement to include them in Arc flash studies. NFPA70E, 2009 edition indicates that IEEE 1584 describes arc flash requirements for 3phase systems rated less than 240VAC. Section 4.2 of IEEE 1584 states “Equipment below 240 V need not be considered unless it involves at least one 125 kVA or larger low impedance transformer in its immediate power supply.”

H. Update arc flash study every [5] years as described in NFPA70E, section 130.5. I. Maintain an electrically safe work place. Insist that all electrical contractors and other outside construction

personnel servicing, maintaining, and/or making adjustments to energized power system equipment are equipped with properly rated PPE based upon the results of this arc flash study prior to start of work.

J. Continue to perform routine preventive maintenance on all circuit breakers and electrical equipment as recommended by [3] at regular service intervals.

2 Calculation Objective

ARC-FLASH HAZARD ANALYSIS – SCOPE: Determine arc-flash incident energy levels and flash protection boundary distances based on the results of the Short-Circuit and Coordination studies. To determine if the first upstream protective device de-energizes the arc fault and if not identify any location where this may occur. Perform the analysis under worst-case arc-flash conditions for all modes of operation. We received transformer available fault current information from the utility and used the values provided by the utility. The values used are as follows:

1. KVA-500 2. Primary Voltage- 12,470 3. Secondary Voltage-480 4. Impedance-4.2 % 5. X/R- 3.69 6. Fuse-Cooper Bay-O-Net 60A

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Identify all locations and equipment to be included in the arc-flash hazard analysis:

1. Include a copy of the facility one-line in the report. 2. Calculate the arcing fault current flowing through each branch for each fault location. 3. Determine the time required to clear the arcing fault current using the protective device settings and associated trip curves. 4. Select the working distances based on system voltage and equipment class. 5. Calculate the incident energy at each fault location at the prescribed working distance. 6. Determine the hazard/risk category (HRC) for the estimated incident energy based on NFPA 70E 2009 Hazard/Risk Categories. 7. Calculate the flash protection boundary at each fault location based on energy at the boundary (EB) of 1.2 Cal/cm2. 8. Document the assessment in reports and one-line diagrams. 9. Furnish labels to be placed on each piece of equipment analyzed. Ship labels to be received by the General Contractor by three weeks to Possession. (Not Included for this report) Results of the arc-flash study shall be summarized in a final report containing the following: 1. Basis, method of hazard assessment, description, purpose, scope, and date of the study.

2. Tabulations of the data used to model the system components and a corresponding one-line diagram. 3. Descriptions of the scenarios evaluated and identification of the scenario used to evaluate equipment ratings. 4. Tabulations of equipment incident energies, hazard risk categories, and flash protection boundaries. The tabulation shall identify and clearly note equipment that exceeds allowable Incident energy ratings. 5. Required arc-flash labels and installation instructions. 6. Conclusions and recommendations

2.1 Objectives The primary goals of this study were as follows:

1 To investigate existing arc flash hazard incident energy (IE) levels at the facility 2 To improve the coordination and selectivity between upstream and downstream overcurrent protective

devices at the plant, if possible, without compromising equipment protection boundaries and selective coordination between upstream and downstream overcurrent protection devices.

3 To report all overcurrent protective devices with inadequate short circuit current interrupting ratings based upon the computed available fault current.

4 Verify arc hazard levels at all panels 208VAC and above.

2.2 Methodology Field data provided for the electrical power system at the facility was used to construct a digital computer model for detailed electrical engineering analysis with the ETAP software program version 12.5.0. Some examples of the typical field data required to perform this analysis include:

1 Motor Nameplate 2 Conductor Sizes and Lengths 3 Transformer Nameplate 4 Utility Thevenin Impedance 5 Breaker Ratings, Settings, and OEM Fuse Ratings and OEM Equipment Bus Short Circuit Rating

The ETAP computer model of the electrical one-line diagram of the store 0.48 kV and 0.208 kV secondary distribution systems is shown in the one-line diagram. The analysis includes a “Base” scenario based upon existing plant conditions and a revision with “minimum” protective device pickup settings with modified device settings and ratings to provide the lowest possible arc flash

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incident energy levels while achieving the best selective coordination between upstream and downstream overcurrent protective devices without compromising existing equipment protection boundaries. When a generator is included in the store, an alternate scenario is run for the generator supplied loads with the main utility disconnected. In this instance the utility case resulted in a higher hazard energy level. An arc-flash hazard analysis is an electrical engineering study’s main purpose to calculate the level of thermal energy exposure to the personnel because of an electric arc-flash event [5]. Computed incident energy levels are largely dependent upon the computed available fault current and device clearing times, which are produced by short circuit current and protective device coordination studies. Based upon the results of the arc flash hazard study, the rating of personal protective equipment (PPE) such as gloves, arc-rated shirts and pants, eye protection, etc…can be properly selected for adequate personnel protection as required by [5]. Note that there is a difference between fire-rated and arc-rated equipment. PPE needed for an arc flash event should have an arc-rating and not just a fire-rated capability.

3 Calculation Method

Arc Flash Analysis Process

IEEE 1584 establishes a nine-step process for gathering information and calculating arc flash hazards. The steps are:

1. Collect Electrical System Data

Collecting system data is the most difficult and time-intensive step in performing an arc flash hazard analysis, but accurate information is vital to correctly calculating flash boundaries. A relatively small error at this point can invalidate all further arc flash calculations. IEEE 1584-2002 lists the minimum information that should be gathered, as shown in the table below. Information collected from facility's electrical system should be recorded and properly documented on the one-line diagram or any other acceptable data collection database. The one-line diagram and electrical database should be kept up to date as much as possible whenever modifications are made to the system .

Component Required Information

Utility SC contribution Initial voltage X/R 3-phase

Transformers

Nominal kVA Primary Voltage Secondary Voltage %Z Impedance

Conductors

Size (AWG) Length Qty. per phase Conductor material Duct material

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Breakers

Model Trip or sensor setting

The following information is as it applies to the particular breaker: Plug, LTPU, LTD, STPU, STD, and INST

Fuses Model Trip

Motors Nominal HP

2. Determine modes of operation

Many electrical systems, especially in smaller commercial facilities, have only a single mode of operation. In large facilities, however, it is common to find a number of operating modes, possibly including: emergency modes in which only backup generators provide power; multiple utility sources or generators that are switched in or out; and motors or portions of the system that may start or cease operation. All of these different modes cause changes in current at various points in the system, altering incident energy and flash boundaries.

3. Determine bolted fault currents

The bolted fault current is the current that would flow through a short circuit consisting of two conductors bolted together. It is the maximum current available to flow through a short circuit. This information is used to calculate the arc fault currents. Bolted fault currents should be determined for each piece of equipment likely to require maintenance or inspection while energized. Information on the minimum bolted fault currents is also needed but typically considered by assuming a minimum number of contributing sources to the fault. It is possible that the worst-case incident energy will occur when the bolted fault current is at a minimum.

4. Determine arc fault currents

The current that flows through an arcing fault may be significantly less than the bolted fault current, due to greater resistance (especially in low voltage equipment). Arc fault current calculations are based on voltage, bolted fault current, conductor gap distance, and other factors. IEEE 1584 presents two formulas for calculating arc fault currents, one for use with 0.208-1 kV systems, and the other for systems between 1 and 15 kV.

For systems between 0.208 and 1 kV:

lg Ia = K + 0.662(lg Ibf) + 0.0966(V) + 0.000526(G) + 0.5588(V)(lg Ibf) - 0.00304(G)(lg Ibf) For systems between 1 and 15 kV:

lg Ia = 0.00402 + 0.983(lg Ibf) where Ia = arc fault current in kA; K = -0.153 for open-air arcs and -0.097 for enclosed arcs; Ibf = 3-phase bolted fault current in kA; V = voltage in kV; G = conductor gap in mm

5. Determine protective device characteristics and duration of arcs

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The time-current curves of upstream protective devices are the major factor in determining how long an arc-fault will last. An effort should be made to determine the actual settings rather than relying on standard values, as these may cause incident energy to vary greatly.

Another consideration when analyzing protective devices is that incident energy depends on both fault current and time. Since protective devices are slower at lower currents, minimum fault currents often pose the worst-case arc flash scenario as mentioned before.

6. Document voltages and equipment classes

Voltage and equipment class determine what equation should be used to find the flash boundary, as well as the bus gap distances required by the equations. Systems operating at <1 kV use a different equation than those operating between 1 kV and 15 kV.

7. Establish working distances

The working distance is the distance from a potential arc source to a worker's face and chest. It is a critical quantity in determining the flash hazard boundary, as even an increase of a few inches in working distance can cause a significant drop in incident energy. 18 inches is the working distance most commonly assumed in calculations, but efforts should be made to determine actual working distances. Some usual working distances are shown in the table below.

Equipment class Working distance

Low-voltage switchgear 24"

15 kV/5 kV switchgear 36"

Low-voltage MCCs and panel boards 18"

Cables 18"

8. Determine incident energies

Incident energy is defined in NFPA 70E as "the amount of energy impressed on a surface, a certain distance from the source, generated during an electrical arc event." In an arc flash hazard study, the "surface" is the worker's body at the assumed working distance. Incident energy is expressed in calories/cm2. IEEE 1584-2002 uses the following formulas (which are also part of NFPA 70E annex D):

(1) E = 4.184(Cf)(En)(t/0.2)(610x/Dx) Where E = incident energy in joules/cm2; Cf is a calculation factor (1.0 for voltages above 1 kV, and 1.5 for voltages below 1 kV); En = normalized incident energy (from equation (2) below); t = arc duration in seconds; D = distance

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from arc in mm; x = distance exponent (see table below)

Equipment Type D (Distance Exponent)

Open air 2.0

Low-voltage (.208-1 kV) switchgear 1.473

High-voltage (1-15 kV) switchgear 0.973

Low-voltage MCCs and panels 1.641

Cables 2.0 (2) lg En = K1 + K2 + 1.081(lg Ia) + 0.0011(G) where En = energy normalized for distance of 610 mm and arc duration of 0.2 seconds, in joules/cm2; K1 = -0.792 for open-air arcs and -0.555 for enclosed arcs; K2 = 0 for ungrounded/high-Z systems and -0.113 for grounded systems; G = arc gap in mm; Ia = predicted 3-phase arc fault current in kA

9. Determine the Arc Flash Boundary (AFB)

The AFB is the distance at which incident energy exposure is about 1.2 cal/cm2, which is equivalent to the energy required to cause the onset of a second-degree burn. The IEEE formula for calculating AFB is:

DB = [4.184(Cf)(En)(t/0.2)(610x/EB)]1/x where EB is the desired incident energy at the boundary (usually 1.2 cal/cm2, but occasionally set at a value matching proposed PPE rating), with other variables defined as for the incident energy equations above.

4 PROTECTIVE DEVICE COORDINATION STUDY 4.1 Discussion The main objectives of the protective device coordination study are to prevent injury to personnel, to minimize damage to system components, and to limit the extent and duration of service interruption whenever equipment failure, human error, or adverse natural events occur on any portion of the electrical power system [4]. The term “selective coordination” simply implies that devices are carefully selected or adjusted to “trip” or operate in a certain desired sequence during fault conditions, preferably beginning with the device closest to the fault followed by the upstream protector(s). Using this methodology, extensive plant outages and safety hazards to personnel and equipment can be avoided by localizing faults to the closest protective device [2]. Based on stated objectives, the settings of molded case circuit breakers (MCCB) and static trip units (STU) were carefully analyzed and adjusted - wherever device adjustments were permissible - in order to obtain “selectivity”

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between upstream and downstream overcurrent protective devices without compromising equipment protective boundaries, transformer inrush, and motor starting criteria. 4.2 Coordination Discrepancies

Coordination discrepancies are best shown graphically by TCC’s which overlap creating an incorrect device tripping sequence. The undesired operation of circuit breakers and can be modified simply by adjusting trip settings to greater than the computed fault current levels (And vice-versa). This operation is preferred to as “blocking” and is represented mathematically by the following expressions:

1 |IF| > |Ip| : Trip (1) 2 |IF| < |Ip| : Do Not Trip (Block) (2) 3 Where: 4 IF = Fault Current 5 IP = Pick-Up Current

This functional dependence between IF and IP is illustrated graphically in Fig. 2[7]. In this study, very few opportunities for adjustments were possible due to the installation of mostly MCCB’s with fixed settings and fuses; however, one coordination discrepancy can be corrected by making proper adjustments to the long time and instantaneous settings of the upstream device and is graphically illustrated in Appendix “E.”

Trip Curves and Settings Time-current characteristic tripping curves (TCC’s) of all applicable fuses, and circuit breakers found in this study are provided in “Appendix B.” The curves are plotted on log-log scale and shown for a “Base” Case, which may represent existing plant overcurrent device settings configured to yield a worst-case scenario (i.e. with settings placed at a maximum pickup value). In addition, a “Recommended” case is included with revised settings required to attain selective coordination, and most importantly, reduce arc flash hazard incident energy levels (Where possible). Also shown are transformer inrush/damage curves, motor starting profile curves, cable and conductor thermal curves, and a miniature section of the one-line diagram where the devices are taken from. These curves and points are plotted to provide a visual, graphical representation of the existing equipment protection boundaries for proper coordination and application of overcurrent protective devices.

5 Short Circuit Study – Design Basis 5.1 Discussion

Short circuit current studies are performed to determine the magnitude of currents flowing throughout the power systems at various time intervals after a “fault” or abnormal condition occurs [4], [6]. These currents must be calculated in order to adequately specify electrical equipment bus withstand ratings and overcurrent protective device interrupting duties. Computer modeling using the ETAP Electrical Engineering software program by PCX was done by expressing the per unit impedances of all relevant electrical power system components (i.e., Transformers, motors, cables, etc…) on a common 100 MVA base and using symmetrical components theory to derive available fault current values at each specific bus. The IEEE 1584 and NFPA 70E methodology only have equations to calculate the arc fault current for three-phase bolted faults. It is likely that arc faults may initiate as line-to-ground faults, but the methodology available makes the conservative assumption that the fault will quickly escalate to a three-phase arc fault.

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5.2 Utility Source Impedance Information Data on Utility Transformer can be provided by ETAP if necessary. 5.3 ANSI/IEEE Fault Current Report

ETAP provides two short current calculation methods based on either ANSI/IEEE or IEC (European) Industry Standards. The following summarizes the ANSI/IEEE short-circuit current method based upon [8], [9], [10], [11]:

5.3.1 ½ Cycle Network This network impedance is used to compute the momentary short circuit current and protective device duties at ½ cycle after the fault occurs. This fault current is used to validate the following:

Device Type Duty 1 HV CB Closing & Latching Rating 2 LV CB Interrupting Rating 3 Fuse Interrupting Rating 4 SWGR/MCC Bus Bracing Rating 5 Relay Instantaneous Trip Settings

The ½ Cycle Network is also preferred to as the “subtransient” impedance network, primarily because all of the AC rotating machines are represented by their subtransient reactance (X”d), as indicated below:

Machine Type Short Circuit Impedance

1 Turbo-Generator X”D 2 Utility X” 3 Induction Machines:

• >1000 Hp @1800 Rpm or Less X”D • >250 Hp @ 3600 Rpm X”D • All Other ≥50 Hp 1.2 X”D

6 ARC FLASH HAZARD ANALYSIS 6.1 Discussion The ultimate goal of an arc-flash hazard analysis (AFHA) is to compute incident energy levels and arc flash boundary distances at all relevant equipment locations in order to determine the thermal energy exposure to which personnel can be exposed when performing energized work. The end-result is the proper selection of arc-rated personal protective equipment (PPE), as prescribed by [5]. Incident energy (IE) level magnitudes, measured in cal/cm2 or joules/cm2, are dependent upon the available 3-phase fault current computed at equipment buses, and perhaps to an even greater degree, the actual total fault current clearing time of the upstream overcurrent protective device(s). Note that according to [1], arc flash hazard calculations pertain to three-phase electrical power systems only. Single-phase power systems and equipment encountered at the plant are not included in the arc flash calculations in this study!

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Wherever possible, the primary objective of the recommendations section of this study is to reduce or “mitigate” incident energy levels by adjusting device trip settings to operate at or below the computed arcing fault current. Personal protective clothing and equipment (PPE) hazard/risk categories 0-4 are specified in [5] with the intent of limiting skin burn injuries to “survivable.” PPE category 4 is the highest of the hazard/risk categories recognized by [5] and requires a minimum arc thermal performance exposure value (ATPV) of 40 cal/cm2 to limit the heat transfer through the material or fabric to a second degree curable burn based upon the Stoll curve. Incident energy levels computed above 40 cal/cm2 are preferred to as “hotspots” within this report and energized work at these locations – If mitigation techniques are ineffective – should be strictly prohibited. Please note that this is a formal incident energy study which determines the actual incident energy available at each location. The choice to report the energy levels as “Categories” defined by NFPA 70E 2009 was made to “easily” communicate the amount of incident energy available. The selection of the ATPV or EB rating of the PPE should factor an additional safety factor above the calculated energy value to reduce any potential break open on the material.

6.2 Arc Flash Results A complete list of arc flash results based upon existing plant conditions are shown in Appendix “F” and recommended changes are given in Section “1” In addition, it has been well documented that a lack of timely electrical preventive maintenance and testing of power circuit breakers could result over time in slower operating/tripping times leading to higher incident energy levels [12]. Therefore, routine preventive maintenance testing of all plant protective relays and power circuit breakers with solid-state trip devices is highly encouraged and recommended. The incident energy values calculated in this study assume an “out-of-the-box” status for all circuit breakers. Their age and maintenance frequency has not been factored into the study. Although higher available fault current levels can affect bus incident energy levels, the results of this study demonstrates that long fault clearing times have an even greater impact on the incident energy calculation.

The arcing current variation (85% of original Ia) has been applied by default on all arc flash scenarios. The worst-case incident energy (100% or 85% Ia) has been reported. Any location where the arcing current variation is a major problem has been identified and recommendations made on how to mitigate the energy have been provided.

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7 REFERENCES 7.1. Acknowledgements Curtis Raymond Helfrich, PE provided his technical assistance in reviewing this ARC Flash Study.

7.2. Bibliography 1. IEEE Standard 1584, “IEEE Guide For Performing Arc-Flash Hazard Calculations,” 2002. 2. NFPA Standard 70, “National Electrical Code,” 2011. 3. International Electrical Testing Association (NETA), “Maintenance Testing Specifications For Electrical Power Distribution Equipment And Systems,” 2005. 4. IEEE Standard 242 (Buff Book), “IEEE Recommended Practice for Protection and Coordination of Industrial and Commercial Power Systems,” 1986. 5. NFPA Standard 70E, “Standard For Electrical Safety Requirements For Employee Workplaces,” 2009. 6. IEEE Standard 399 (Brown Book), “IEEE Recommended Practice for Industrial and Commercial Power Systems Analysis,” 1990. 7. Stevenson, William D, Jr., “Elements of Power System Analysis,” McGraw-Hill, Inc., 1982. 8. ANSI/IEEE Standard C37.04, “Standard Rating Structure for AC High Voltage Circuit Breakers Rated on a Symmetrical Current Basis,” 1999. 9. ANSI/IEEE Standard C37.010, “Standard Application Guide for AC High Voltage Circuit Breakers Rated on a Symmetrical Current Basis,” 1999. 10. ANSI/IEEE Standard C37.13, “Standard for Low-Voltage AC Circuit Breakers Used in Enclosures,” 1990. 11. ANSI/IEEE Standard C37.20.1, “Standard for Metal Enclosed Low-Voltage Power Circuit Breaker Switchgear,” 2002. 12. Neitzel, Dennis K., “Protective Devices Maintenance as It Applies To the Arc/Flash Hazard,” 2004.

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Appendix A: ETAP One-Line diagram

A one-line diagram was generated for the Store #XXXX for analysis purposes. The worst case analysis drawing is attached showing the AFH for each bus and panel.

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Appendix B: INPUT DATA & Assumptions

In instances where credible data was not supplied or available, valid engineering assumptions for the ETAP computer model were made based upon the specific application and professional engineering experience and judgment. The following are known assumptions for this study: The incident energy has been conservatively estimated for most locations downstream from the main 1600 Amp circuit breaker. Energy results for the 1600 Amp main circuit breaker compartment are not available since information on the upstream primary side transformer protection is not available. An incident energy result projected based on a 1.5 sec maximum exposure time has been provided. The actual incident energy value can be determined once the missing information is obtained.

Customer Store #XXXX

Address 544 Industrial Loop

City, State, zip Shreveport, LA 71129

Contact name John Doe

Phone XXX-XXX-XXXX Utility Company XXXX Power Co. Contact Ernest Duncan Address 6130 Union Ave. City State Zip Shreveport, LA 71108 Email [email protected]

Phone XXX-XXX-XXXX General Contractor XXXX Construction Contact Justin Wells Address 1102 S. Happy Hollow Rd. City State Zip Fayetteville, AR 72701 Email [email protected]

Phone XXX-XXX-XXX

mailto:[email protected]

mailto:[email protected]

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Appendix C: Coordination study report – including overcurrent protective device settings

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ETAP Project: STORE#XXXX

Location: City, State

Contract:

Engineer: XX

Filename: PCXXXXX

Page: 1

Date: XX-XX-2016

Revision: Base

Protective Device Settings

12.6.0C

CB: CB-AHU1Tag #:MFR: General Electric

Model: SFLA

Cont. Amp: 250.000

Rating: 65 kA, 0.48 kV

3-Phase kA: 0.00 Asym. (Calc.)

LG kA: 0.00 Asym. (Calc.)

Base kV: 0.000 (Calc.)Size: 250

Sensor: 250

MFR: General Electric

Model: Spectra RMS SF

LV Solid State Trip Device

Rating Plug: 225.00

Phase Setting

LT Pickup FixedLong-Time

LT Band Fixed

ST Pickup FixedShort-Time

ST Band Fixed I^xt=IN

Inst. Pickup MAXINST

CB: CB-BalerTag #:MFR: General Electric

Model: SELA

Cont. Amp: 30.000





Sensor: 30


Model: Spectra RMS SE


Rating Plug: 30.00

Phase Setting


LT Band Fixed




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Contract:

Engineer: XX

Filename: PCXXXXX

Page: 2

Date: XX-XX-2016

Revision: Base


12.6.0C

CB: CB-CompactorTag #:MFR: General Electric

Model: SELA

Cont. Amp: 30.000





Sensor: 30




Rating Plug: 30.00

Phase Setting


LT Band Fixed




CB: CB-DTATag #:MFR: General Electric

Model: SGLA

Cont. Amp: 600.000





Sensor: 600


Model: Spectra RMS SG


Rating Plug: 450.00

Phase Setting


LT Band Fixed



Inst. Pickup 5INST

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Contract:

Engineer: XX

Filename: PCXXXXX

Page: 3

Date: XX-XX-2016

Revision: Base


12.6.0C

CB: CB-H1ATag #:MFR: General Electric

Model: SGLA

Cont. Amp: 400.000





Sensor: 400


Model: Spectra RMS SG


Rating Plug: 400.00

Phase Setting


LT Band Fixed



Inst. Pickup 5INST

CB: CB-H1PTag #:MFR: General Electric

Model: SELA

Cont. Amp: 100.000





Sensor: 100




Rating Plug: 100.00

Phase Setting


LT Band Fixed



Inst. Pickup MININST

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Contract:

Engineer: XX

Filename: PCXXXXX

Page: 4

Date: XX-XX-2016

Revision: Base


12.6.0C

CB: CB-MBUTag #:MFR: General Electric

Model: SS 1600 ETU

Cont. Amp: 1600.000





Sensor: 1600 (LSIG)


Model: Entelliguard


Rating Plug: 1600.00

Phase Setting Ground Setting

LT Pickup 1.000Long-Time Ground Pickup 0.400

LT Band 1 Ground Band 1 I^xt=OUT

ST Pickup 4.000Short-Time

ST Band 1 I^xt=OUT

Inst. Pickup 3.000INST

CB: CB-MTBTag #:MFR: General Electric

Model: SFLA

Cont. Amp: 250.000





Sensor: 250




Rating Plug: 200.00

Phase Setting


LT Band Fixed




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Contract:

Engineer: XX

Filename: PCXXXXX

Page: 5

Date: XX-XX-2016

Revision: Base


12.6.0C

CB: CB-Oven(Bottom)Tag #:MFR: General Electric

Model: SELA

Cont. Amp: 100.000





Sensor: 70




Rating Plug: 70.00

Phase Setting


LT Band Fixed




CB: CB-Oven(Top)Tag #:MFR: General Electric

Model: SELA

Cont. Amp: 60.000





Sensor: 40




Rating Plug: 40.00

Phase Setting


LT Band Fixed




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Contract:

Engineer: XX

Filename: PCXXXXX

Page: 6

Date: XX-XX-2016

Revision: Base


12.6.0C

CB: CB-PLMTag #:MFR: General Electric

Model: SELA

Cont. Amp: 30.000





Sensor: 15




Rating Plug: 15.00

Phase Setting


LT Band Fixed




CB: CB-Sub-MeteringTag #:MFR: General Electric

Model: SELA

Cont. Amp: 30.000





Sensor: 15




Rating Plug: 15.00

Phase Setting


LT Band Fixed




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Contract:

Engineer: XX

Filename: PCXXXXX

Page: 7

Date: XX-XX-2016

Revision: Base


12.6.0C

CB: CB-T1DTag #:MFR: General Electric

Model: SFLA

Cont. Amp: 250.000





Sensor: 250




Rating Plug: 225.00

Phase Setting


LT Band Fixed




CB: CB-UH (Vestibule)Tag #:MFR: General Electric

Model: SELA

Cont. Amp: 60.000





Sensor: 50




Rating Plug: 50.00

Phase Setting


LT Band Fixed




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Contract:

Engineer: XX

Filename: PCXXXXX

Page: 8

Date: XX-XX-2016

Revision: Base


12.6.0C

CB: CB-Water HeaterTag #:MFR: General Electric

Model: SELA

Cont. Amp: 100.000





Sensor: 70




Rating Plug: 70.00

Phase Setting


LT Band Fixed




SAMPLE REPORT

CB-Oven(Top)

CB-Sub-Metering

CB-Compactor

CB-Oven(Bottom)

CB-Water Heater

CB-UH (Vestibule)

CB-PLM

CB-Baler

CB-H1P

CB-H1A

CB-T1D

CB-AHU1

CB-MTB

CB-DTA

CB-MBG

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K

Amps X 10 MSB (Distribution) (Nom. kV=0.48, Plot Ref. kV=0.48)

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seco

nds

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

ETAP Star 12.6.0C

MBG COORDINATION

Project: STORE#XXXXLocation: City, STContract: PCXXXXXEngineer: XXFilename:

Date: XX-XX-2016 SN: PCX-CORP01 Rev: BaseFault: Phase

CB-MBG

CB-H1A CB-H1P CB-T1D CB-DTA CB-MTB CB-AHU1 CB-Baler CB-Compactor CB-Sub-Metering CB-Oven(Top) CB-Oven(Bottom) CB-PLMCB-UH (Vestibule)

CB-Water Heater

CB-H1A CB-AHU1CB-DTA CB-Oven(Bottom)CB-Oven(Top)

CB-Water Heater

CB-BalerCB-UH (Vestibule)

CB-Sub-MeteringCB-H1P CB-Compactor CB-PLMCB-T1D CB-MTB

CB-MBG

SAMPLE REPORT

CB-Oven(Top)

CB-Sub-Metering

CB-Compactor

CB-Oven(Bottom)

CB-Water Heater

CB-UH (Vestibule)

CB-PLM

CB-Baler

CB-H1P

CB-H1A

CB-T1D

CB-AHU1

CB-MTB

CB-DTA

CB-MBU

10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


10K.5 1 10 100 1K3 5 30 50 300 500 3K 5K


1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seco

nds

1K

.01

.1

1

10

100

.03

.05

.3

.5

3

5

30

50

300

500

Seconds

ETAP Star 12.6.0C

MBU COORDINATION

Project: STORE#XXXXLocation: City, STContract: PCXXXXXEngineer: XXFilename:

Date: XX-XX-2016 SN: PCX-CORP01 Rev: BaseFault: Phase

CB-MBU

CB-H1A CB-H1P CB-T1D CB-DTA CB-MTB CB-AHU1 CB-Baler CB-Compactor CB-Sub-Metering CB-Oven(Top) CB-Oven(Bottom) CB-PLMCB-UH (Vestibule)

CB-Water Heater

CB-PLMCB-Sub-MeteringCB-Compactor

CB-Water Heater

CB-BalerCB-DTA CB-Oven(Top)CB-UH (Vestibule)

CB-Oven(Bottom)CB-MTBCB-H1A CB-H1P CB-T1D

CB-MBU

CB-AHU1

SAMPLE REPORT




Appendix D: Short Circuit results

SAMPLE REPORT

Location:

Study Case: SC Normal

12.6.0CPage: 1

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX

Project: STORE#XXXX ETAP

Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Electrical Transient Analyzer Program

Short-Circuit Analysis

ANSI Standard

3-Phase Fault Currents

Number of Buses:

Number of Branches:

Number of Machines:

28

7

1

3

2

3

23

29

0

0

28

1

0

0

0

2

1

Swing V-Control TotalLoad

XFMR2 Total Tie PDImpedanceLine/CableReactorXFMR3

Synchronous

Generator Total

Lumped

Load

Induction

Machines

Synchronous

Motor

Power

Grid

Unit System:

Project Filename:

Output Filename:

System Frequency: 60.00 Hz

English

PCXXXXX

SAMPLE REPORT

Location:


12.6.0CPage: 2

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Adjustments

Transformer Impedance:

Reactor Impedance:

Tolerance

Overload Heater Resistance:

Transmission Line Length:

Cable Length:

Temperature Correction

Transmission Line Resistance:

Cable Resistance:

Percent

Degree C

Individual

/Global

Individual

/Global

Individual

Individual

Individual

Individual

Apply

Adjustments

Apply

Adjustments

Yes

Yes

No

No

No

Yes

Yes

SAMPLE REPORT

Location:


12.6.0CPage: 3

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Bus Input Data

ID Type

Bus

Sub-sys

Initial Voltage

%Mag. Ang.Base kVNom. kV

0.480 0.480LoadB-AHU1 1 0.00 100.00

0.480 0.480LoadB-Baler 1 0.00 1.00

0.480 0.480LoadB-Compactor 1 0.00 100.00

0.480 0.480LoadB-Oven(Bottom) 1 0.00 100.00

0.480 0.480LoadB-Oven(Top) 1 0.00 100.00

0.480 0.480LoadB-PLM 1 0.00 100.00

0.480 0.480LoadB-Sub-Metering 1 0.00 100.00

0.480 0.480LoadB-T1D Pri 1 0.00 100.00

0.208 0.208LoadB-T1D Sec 1 0.00 100.00

0.480 0.480LoadB-UH (Vestibule) 1 0.00 100.00

0.208 0.208LoadB-UPS1 Pri 1 0.00 100.00

0.208 0.208LoadB-UPS1 Sec 1 0.00 100.00

12.470 13.200SWNGB-Utility Primary 1 0.00 94.47

0.480 0.480LoadB-Utility Secondary 1 0.00 100.00

0.480 0.480LoadB-Water Heater 1 0.00 100.00

0.208 0.208LoadCircuit Breaker L1D2 1 0.00 100.00

0.480 0.480LoadMSB (Distribution) 1 0.00 1.00

0.480 0.480LoadMSB (Gen) 1 0.00 100.00

0.480 0.480LoadMSB (Main Breaker) 1 0.00 100.00

0.480 0.480LoadPanel DTA 1 0.00 100.00

0.480 0.480LoadPanel H1A 1 0.00 100.00

0.480 0.480LoadPanel H1P 1 0.00 100.00

0.208 0.208LoadPanel L1D1-1 1 0.00 100.00

0.208 0.208LoadPanel L1D1-2 1 0.00 1.00

0.208 0.208LoadPanel L1D2-1 1 0.00 100.00

0.208 0.208LoadPanel L1D2-2 1 0.00 100.00

0.208 0.208LoadPanel L1U 1 0.00 100.00

0.208 0.208LoadPanel LRX 1 0.00 100.00

0.480 0.480LoadPanel MTB 1 0.00 100.00

29 Buses Total

All voltages reported by ETAP are in % of bus Nominal kV.

Base kV values of buses are calculated and used internally by ETAP .

SAMPLE REPORT

Location:


12.6.0CPage: 4

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Line/Cable Input Data

ID Library Size #/Phase T (°C) R

Line/Cable

Ohms or Siemens/1000 ft per Conductor (Cable) or per Phase (Line)

Adj. (ft) % Tol.

Length

YX

C-AHU1 0.6MCUN1 4/0 290.0 1 0.06300 75 0 0.0000000 0.05100

C-Baler 0.6MCUN1 10 270.0 1 1.20000 75 0 0.0000000 0.06300

C-Compactor 0.6MCUN1 10 275.0 1 1.20000 75 0 0.0000000 0.06300

C-DTA 0.6MALN1 300 235.0 2 0.07200 75 0 0.0000000 0.05100

C-H1A 0.6MALN1 250 9.0 2 0.08600 75 0 0.0000000 0.05200

C-H1P 1.0MALN1 1 12.0 1 0.25000 75 0 0.0000000 0.05700

C-L1D1-1 0.6MALN1 300 5.0 1 0.07200 75 0 0.0000000 0.05100

C-L1D1-2 0.6MALN1 300 3.0 1 0.07200 75 0 0.0000000 0.05100

C-L1D2 Line 0.6MALN1 250 3.0 2 0.08600 75 0 0.0000000 0.05200

C-L1D2 Load 0.6MALN1 250 280.0 2 0.08600 75 0 0.0000000 0.05200

C-L1D2-2 0.6MALN1 250 3.0 2 0.08600 75 0 0.0000000 0.05200

C-L1U 0.6MCUN1 6 50.0 1 0.49000 75 0 0.0000000 0.06400

C-LRX 0.6MALN1 4 160.0 1 0.51000 75 0 0.0000000 0.06000

C-MBU 0.6MCUN1 300 60.0 6 0.04500 75 0 0.0000000 0.05100

C-MTB 0.6MALN1 250 260.0 1 0.08600 75 0 0.0000000 0.05200

C-Oven(Bottom) 0.6MCUN1 2 275.0 1 0.20000 75 0 0.0000000 0.05700

C-Oven(Top) 0.6MCUN1 8 275.0 1 0.78000 75 0 0.0000000 0.06500

C-PLM 0.6MCUN1 12 5.0 1 2.00000 75 0 0.0000000 0.06800

C-Sub-Metering 0.6MCUN1 12 5.0 1 2.00000 75 0 0.0000000 0.06800

C-T1D Pri 0.6MALN1 300 9.0 1 0.07200 75 0 0.0000000 0.05100

C-UH (Vestibule) 0.6MCUN1 6 5.0 1 0.49000 75 0 0.0000000 0.06400

C-UPS1 0.6MCUN1 6 40.0 1 0.49000 75 0 0.0000000 0.06400

C-Water Heater 0.6MCUN1 2 5.0 1 0.20000 75 0 0.0000000 0.05700

Line / Cable resistances are listed at the specified temperatures.

SAMPLE REPORT

Location:


12.6.0CPage: 5

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

2-Winding Transformer Input Data

ID MVA Prim. kV Sec. kV % Z X/R Prim. Sec.

Transformer % Tap Setting

% Tol.

Rating Z Variation

+ 5% - 5% % Z

Adjusted

T1D 0.150 0.480 0.208 4.00 3.45 2.500 2.500 0 0 0 4.0000

Utility Transformer 0.500 12.470 0.480 4.20 5.10 0 0 0 0 0 4.2000

Impedance Input Data

ID R X Y Unit

Impedance Positive Sequence Impedanc

MSB Bus % in 0.480 kV base and 100.0 MVA base 0.01 0.01 0

% in 0.480 kV base and 100.0 MVA baseMSB Bus 2 0.01 0.01 0

SAMPLE REPORT

Location:


12.6.0CPage: 6

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Branch Connections

ID From Bus To Bus R X ZType

CKT/Branch % Impedance, Pos. Seq., 100 MVAbConnected Bus ID

Y

T1D B-T1D Pri 779.97 2690.91 2801.67B-T1D Sec2W XFMR

Utility Transformer B-Utility Primary 161.63 824.30 840.00B-Utility Secondary2W XFMR

C-AHU1 MSB (Distribution) 792.97 641.93 1020.23B-AHU1Cable

C-Baler MSB (Distribution) 14062.50 738.28 14081.87B-BalerCable

C-Compactor MSB (Distribution) 14322.92 751.95 14342.64B-CompactorCable

C-DTA MSB (Distribution) 367.19 260.09 449.97Panel DTACable

C-H1A MSB (Distribution) 16.80 10.16 19.63Panel H1ACable

C-H1P MSB (Distribution) 130.21 29.69 133.55Panel H1PCable

C-L1D1-1 B-T1D Sec 83.21 58.94 101.97Panel L1D1-1Cable

C-L1D1-2 Panel L1D1-1 49.93 35.36 61.18Panel L1D1-2Cable

C-L1D2 Line B-T1D Sec 29.82 18.03 34.84Circuit Breaker L1D2Cable

C-L1D2 Load Circuit Breaker L1D2 2782.91 1682.69 3252.09Panel L1D2-1Cable


C-L1U B-UPS1 Sec 5662.91 739.65 5711.01Panel L1UCable

C-LRX Panel L1D1-1 18860.95 2218.94 18991.02Panel LRXCable

C-MBU B-Utility Secondary 19.53 22.14 29.52MSB (Main Breaker)Cable

C-MTB MSB (Distribution) 970.49 586.81 1134.10Panel MTBCable

C-Oven(Bottom) MSB (Distribution) 2387.15 680.34 2482.21B-Oven(Bottom)Cable

C-Oven(Top) MSB (Distribution) 9309.90 775.82 9342.17B-Oven(Top)Cable

C-PLM MSB (Distribution) 434.03 14.76 434.28B-PLMCable

C-Sub-Metering MSB (Distribution) 434.03 14.76 434.28B-Sub-MeteringCable

C-T1D Pri MSB (Distribution) 28.13 19.92 34.47B-T1D PriCable

C-UH (Vestibule) MSB (Distribution) 106.34 13.89 107.24B-UH (Vestibule)Cable

C-UPS1 Panel L1D2-1 4530.33 591.72 4568.81B-UPS1 PriCable

C-Water Heater MSB (Distribution) 43.40 12.37 45.13B-Water HeaterCable

MSB Bus MSB (Main Breaker) 0.01 0.01 0.01MSB (Distribution)Impedance

MSB Bus 2 MSB (Gen) 0.01 0.01 0.01MSB (Distribution)Impedance

UPS1 B-UPS1 Pri B-UPS1 SecTie Switch

SAMPLE REPORT

Location:


12.6.0CPage: 7

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Power Grid Input Data

ID ID MVASC kV R X

Rating

X/R

100 MVA Base% Impedance

Power Grid Connected Bus

Utility 12.470 164.35170 44.53977 58.727B-Utility Primary 3.69

Total Connected Power Grids (= 1 ): 58.727 MVA

SAMPLE REPORT

Location:


12.6.0CPage: 8

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Induction Machine Input Data

kVA kV RPM X"/R X'/R R X'X"

Induction Machine Rating X/R Ratio Machine BaseConnected Bus

IDID

% Impedance

HP/kWQty

Motors

Load AHU1 1 B-AHU1 0.480 2.07 9.66 9.66 1800 20.00 50.00 154.00 147.23

Load Baler 1 B-Baler 0.480 11.06 2.52 2.52 1800 27.83 9999.00 10.45 11.65

Load Compactor 1 B-Compactor 0.480 11.06 2.52 2.52 1800 27.83 9999.00 10.45 11.65

Total Connected Induction Motors ( = 3 ): 170.5 kVA

SAMPLE REPORT

Location:


12.6.0CPage: 9

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Lumped Load Input Data

IDID kVA kV X"/R X'/R R X'X"

Lumped Load Rating X/R Ratio (Machine Base)

kW kvar

Loading

MTR STAT

% Load Loading

kW kvar

Lumped Load

Connected Bus

Motor Loads Static Loads

% Imp.

Load DTA 0.480 100 0 2.38 2.38 8.403 20.00 50.00Panel DTA 328.0 172.8 278.8 0.00 0.00

Load H1A 0.480 100 0 2.38 2.38 8.403 20.00 50.00Panel H1A 286.0 150.7 243.1 0.00 0.00

Load MTB 0.480 100 0 2.38 2.38 8.403 20.00 50.00Panel MTB 130.0 68.5 110.5 0.00 0.00

Total Connected Lumped Loads ( = 3 ): 744.0 kVA

SAMPLE REPORT

Location:


12.6.0CPage: 10

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

SHORT-CIRCUIT REPORT

3-phase fault at bus: MSB (Distribution)

Prefault voltage = 0.480 = 100.00 % of nominal bus kV ( 0.480 kV)

= 100.00 % of base ( 0.480 kV)

ID Magnitude/RealRealFrom BusID Imaginary

From Bus To Bus % V kA kA Imag. kA Symm.

Contribution 1/2 Cycle

Total 16.458 3.7 4.319 0.00MSB (Distribution) -15.881

MSB (Distribution) 0.836 6.5 0.128 7.09B-AHU1 -0.826

MSB (Distribution) 0.046 2.2 0.019 5.35B-Baler -0.042

MSB (Distribution) 0.046 2.2 0.019 5.45B-Compactor -0.042

MSB (Distribution) 1.718 2.2 0.719 6.43Panel DTA -1.561

MSB (Distribution) 1.582 2.4 0.615 0.26Panel H1A -1.458

MSB (Distribution) 0.000 999.9 0.000 0.00Panel H1P 0.000

MSB (Distribution) 0.683 2.1 0.288 6.44Panel MTB -0.619

MSB (Distribution) 0.000 999.9 0.000 0.00B-Oven(Bottom) 0.000

MSB (Distribution) 0.000 999.9 0.000 0.00B-Oven(Top) 0.000

MSB (Distribution) 0.000 999.9 0.000 0.00B-PLM 0.000

MSB (Distribution) 0.000 999.9 0.000 0.00B-Sub-Metering 0.000

MSB (Distribution) 0.000 999.9 0.000 0.00B-T1D Pri 0.000

MSB (Distribution) 0.000 999.9 0.000 0.00B-UH (Vestibule) 0.000

MSB (Distribution) 0.000 999.9 0.000 0.00B-Water Heater 0.000

MSB (Distribution) 11.614 4.5 2.531 0.00MSB (Main Breaker) -11.334

MSB (Distribution) 0.000 999.9 0.000 0.00MSB (Gen) 0.000

NACD Ratio = 1.00

# Indicates a fault current contribution from a three-winding transformer

* Indicates a fault current through a tie circuit breaker

If faulted bus is involved in loops formed by protection devices, the short-circuit contributions through these PDs will not be reported.

SAMPLE REPORT

Location:


12.6.0CPage: 11

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

3-phase fault at bus: MSB (Main Breaker)


= 100.00 % of base ( 0.480 kV)




Total 16.458 3.7 4.319 0.00MSB (Main Breaker) -15.881

MSB (Main Breaker) 11.614 4.5 2.531 2.85B-Utility Secondary -11.335

MSB (Main Breaker) 4.885 2.5 1.788 0.00MSB (Distribution) -4.546

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 12

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

3-phase fault at bus: Panel DTA


= 100.00 % of base ( 0.480 kV)




Total 11.895 1.9 5.487 0.00Panel DTA -10.554

Panel DTA 10.084 1.9 4.783 37.72MSB (Distribution) -8.877

Panel DTA 1.819 2.4 0.704 100.00Load DTA -1.677

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 13

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

3-phase fault at bus: Panel H1A


= 100.00 % of base ( 0.480 kV)




Total 16.209 3.5 4.491 0.00Panel H1A -15.574

Panel H1A 14.635 3.6 3.876 2.39MSB (Distribution) -14.112

Panel H1A 1.586 2.4 0.614 100.00Load H1A -1.462

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 14

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

3-phase fault at bus: Panel H1P


= 100.00 % of base ( 0.480 kV)




Total 14.991 2.3 6.016 0.00Panel H1P -13.731

Panel H1P 14.991 2.3 6.016 16.64MSB (Distribution) -13.731

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 15

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

3-phase fault at bus: Panel L1D1-1


= 100.00 % of base ( 0.208 kV)




Total 7.626 3.2 2.269 0.00Panel L1D1-1 -7.280

Panel L1D1-1 7.626 3.2 2.269 2.80B-T1D Sec -7.280

Panel L1D1-1 0.000 999.9 0.000 0.00Panel L1D1-2 0.000

Panel L1D1-1 0.000 999.9 0.000 0.00Panel LRX 0.000

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 16

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal



= 100.00 % of base ( 0.208 kV)




Total 7.525 3.1 2.311 0.00Panel L1D1-2 -7.161

Panel L1D1-2 7.525 3.1 2.311 1.66Panel L1D1-1 -7.161

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 17

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal



= 100.00 % of base ( 0.208 kV)




Total 4.350 1.3 2.599 0.00Panel L1D2-1 -3.488

Panel L1D2-1 4.350 1.3 2.599 50.96Circuit Breaker L1D2 -3.488

Panel L1D2-1 0.000 999.9 0.000 0.00Panel L1D2-2 0.000

Panel L1D2-1 0.000 999.9 0.000 0.00B-UPS1 Pri 0.000

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 18

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal



= 100.00 % of base ( 0.208 kV)




Total 4.328 1.3 2.593 0.00Panel L1D2-2 -3.465

Panel L1D2-2 4.328 1.3 2.593 0.54Panel L1D2-1 -3.465

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 19

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

3-phase fault at bus: Panel L1U


= 100.00 % of base ( 0.208 kV)




Total 1.800 0.5 1.635 0.00Panel L1U -0.753

Panel L1U 1.800 0.5 1.635 37.04B-UPS1 Sec -0.753

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 20

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

3-phase fault at bus: Panel LRX


= 100.00 % of base ( 0.208 kV)




Total 1.338 0.3 1.287 0.00Panel LRX -0.367

Panel LRX 1.338 0.3 1.287 91.56Panel L1D1-1 -0.367

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 21

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

3-phase fault at bus: Panel MTB


= 100.00 % of base ( 0.480 kV)




Total 7.508 1.2 4.786 0.00Panel MTB -5.785

Panel MTB 6.822 1.1 4.507 64.32MSB (Distribution) -5.120

Panel MTB 0.721 2.4 0.279 100.00Load MTB -0.665

NACD Ratio = 1.00




SAMPLE REPORT

Location:


12.6.0CPage: 22

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

CIty, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Momentary Duty Summary Report

3-Phase Fault Currents: (Prefault Voltage = 100 % of the Bus Nominal Voltage)

ID kA PeakkA rmskA rmskA PeakkA rmsM.F.RatiokA rmsTypeIDkV

Symm. X/R Asymm. Asymm. Symm. Asymm. Asymm.

Momentary DutyDeviceBus Device Capability

33.880 19.579 1.190 4.0 16.458MSB (Distribution) 0.480MSB (Distribution) Switchboard

33.880 19.579 1.190 4.0 16.458MSB (Main Breaker) 0.480MSB (Main Breaker) Switchboard

20.213 12.369 1.040 2.0 11.895Panel DTA 0.480Panel DTA Panelboard

32.795 18.978 1.171 3.7 16.209Panel H1A 0.480Panel H1A Panelboard

26.890 16.034 1.070 2.4 14.991Panel H1P 0.480Panel H1P Panelboard

14.891 8.661 1.136 3.3 7.626Panel L1D1-1 0.208Panel L1D1-1 Panelboard




2.549 1.800 1.000 0.5 1.800Panel L1U 0.208Panel L1U Panelboard

1.893 1.338 1.000 0.3 1.338Panel LRX 0.208Panel LRX Panelboard

11.468 7.556 1.006 1.2 7.508Panel MTB 0.480Panel MTB Panelboard

Method: IEEE - X/R is calculated from separate R & X networks.

* Indicates a device with momentary duty exceeding the device capability

Protective device duty is calculated based on total fault current.

The multiplication factors for high voltage circuit-breaker and high voltage bus momentary duty (asymmetrical and crest values) are calculated based on system X/R.

SAMPLE REPORT

Location:


12.6.0CPage: 23

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Interrupting Duty Summary Report

3-Phase Fault Currents: (Prefault Voltage = 100 % of the Bus Nominal Voltage)

ID Int.PFkVkA rmsM.F.RatiokA rmsTypeIDkV

Symm. X/R Adj. Sym. Test

Interrupting Duty

Int.

DeviceBus Device Capability

Rated Adjusted

(Cy)

CPT

MSB (Distribution) 0.480 CB-H1A MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-H1P MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-T1D MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-DTA MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-Oven(Top) MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-Sub-Metering MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-Compactor MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-Baler MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-AHU1 MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-MTB MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-Oven(Bottom) MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-PLM MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-UH (Vestibule) MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

CB-Water Heater MoldedFused 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

MSB (Main Breaker) 0.480 CB-MBU InsulUnfuse 16.458 4.0 1.000 16.458 0.480 20.00 65.000 65.000

Panel DTA 0.480 11.895 2.0

Panel H1A 0.480 16.209 3.7

Panel H1P 0.480 14.991 2.4

Panel L1D1-1 0.208 CB-L1D1 Molded Case 7.626 3.3 1.107 8.440 0.240 50.00 10.000 10.000

CB-LRX Molded Case 7.626 3.3 1.107 8.440 0.240 50.00 10.000 10.000

Panel L1D1-2 0.208 7.525 3.1

Panel L1D2-1 0.208 CB-L1U Molded Case 4.350 1.3 1.000 4.350 0.240 50.00 10.000 10.000

Panel L1D2-2 0.208 4.328 1.3

Panel L1U 0.208 1.800 0.5

Panel LRX 0.208 1.338 0.3

Panel MTB 0.480 7.508 1.2

Method: IEEE - X/R is calculated from separate R & X networks.

HV CB interrupting capability is adjusted based on bus nominal voltage

Generator protective device duty is calculated based on maximum through fault current. Other protective device duty is calculated based on total fault current.

Short-circuit multiplying factor for LV Molded Case and Insulated Case Circuit Breakers is calculated based on asymmetrical current.

* Indicates a device with interrupting duty exceeding the device capability

** Indicates that the circuit breaker has been flagged as a generator circuit breaker. However, ETAP could not detect a single path, without a transformer, to the specified generator.

Therefore, this circuit breaker is treated as a regular circuit breaker in short-circuit calculations.

+ The prefault voltage exceeds the rated maximum kV limit of the circuit breaker - The rated interrupting kA must be derated.

SAMPLE REPORT




Appendix E: Arc Flash results

SAMPLE REPORT

Location:


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Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Electrical Transient Analyzer Program

ANSI Short-Circuit

IEEE 1584

Arc Flash Analysis

Number of Buses:

Number of Branches:

Number of Machines:

1 0 28

2 0 23 0 2 1

0 0 3 3 1

29

28

7

Swing V-Control TotalLoad

XFMR2 Total Tie PDImpedanceLine/CableReactorXFMR3

Synchronous

Generator Total

Lumped

Load

Induction

Machines

Synchronous

Motor

Power

Grid

Unit System:

Project Filename:

Output Filename:

System Frequency: 60.00 Hz

English

PCXXXXX

SAMPLE REPORT

Location:


12.6.0CPage: 2

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Adjustments

Transformer Impedance:

Reactor Impedance:

Tolerance

Overload Heater Resistance:

Transmission Line Length:

Cable Length:

Temperature Correction

Transmission Line Resistance:

Cable Resistance:

Percent

Degree C

Individual

/Global

Individual

/Global

Individual

Individual

Individual

Individual

Apply

Adjustments

Apply

Adjustments

Yes

Yes

No

No

No

Yes

Yes

NFPA 70E 2009

cal/cm²Level ID

Energy Levels

1.20Level 0

4.00Level 1

8.00Level 2

25.00Level 3

40.00Level 4

SAMPLE REPORT

Location:


12.6.0CPage: 3

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Bus Input Data

ID Type Nom. kV

Bus

Base kV

Initial Voltage

%Mag. Ang.Sub-sys

0.480 0.480LoadB-AHU1 1 100.00 0.00

0.480 0.480LoadB-Baler 1 1.00 0.00

0.480 0.480LoadB-Compactor 1 100.00 0.00

0.480 0.480LoadB-Oven(Bottom) 1 100.00 0.00

0.480 0.480LoadB-Oven(Top) 1 100.00 0.00

0.480 0.480LoadB-PLM 1 100.00 0.00

0.480 0.480LoadB-Sub-Metering 1 100.00 0.00

0.480 0.480LoadB-T1D Pri 1 100.00 0.00

0.208 0.208LoadB-T1D Sec 1 100.00 0.00

0.480 0.480LoadB-UH (Vestibule) 1 100.00 0.00

0.208 0.208LoadB-UPS1 Pri 1 100.00 0.00

0.208 0.208LoadB-UPS1 Sec 1 100.00 0.00

12.470 13.200SWNGB-Utility Primary 1 94.47 0.00

0.480 0.480LoadB-Utility Secondary 1 100.00 0.00

0.480 0.480LoadB-Water Heater 1 100.00 0.00

0.208 0.208LoadCircuit Breaker L1D2 1 100.00 0.00

0.480 0.480LoadMSB (Distribution) 1 1.00 0.00

0.480 0.480LoadMSB (Gen) 1 100.00 0.00

0.480 0.480LoadMSB (Main Breaker) 1 100.00 0.00

0.480 0.480LoadPanel DTA 1 100.00 0.00

0.480 0.480LoadPanel H1A 1 100.00 0.00

0.480 0.480LoadPanel H1P 1 100.00 0.00

0.208 0.208LoadPanel L1D1-1 1 100.00 0.00

0.208 0.208LoadPanel L1D1-2 1 1.00 0.00

0.208 0.208LoadPanel L1D2-1 1 100.00 0.00

0.208 0.208LoadPanel L1D2-2 1 100.00 0.00

0.208 0.208LoadPanel L1U 1 100.00 0.00

0.208 0.208LoadPanel LRX 1 100.00 0.00

0.480 0.480LoadPanel MTB 1 100.00 0.00

29 Buses Total

All voltages reported by ETAP are in % of bus Nominal kV.

Base kV values of buses are calculated and used internally by ETAP .

SAMPLE REPORT

Location:


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SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Bus Arc Flash Input Data

ID Nom. kV

Faulted Bus

Equip. Type Gap (mm) X Factor

Arc Flash Ratings

Exp. Movable Fixed Circuit Restricted Prohibited

Limited Approach Boundary (ft)Avail. Protection

cal/cm²

MSB (Distribution) 32 1.473Switchboard 0.480 10.000 3.500 1.000 0.100 0.0

MSB (Main Breaker) 32 1.473Switchboard 0.480 10.000 3.500 1.000 0.100 0.0

Panel DTA 25 1.641Panelboard 0.480 10.000 3.500 1.000 0.100 0.0

Panel H1A 25 1.641Panelboard 0.480 10.000 3.500 1.000 0.100 0.0

Panel H1P 25 1.641Panelboard 0.480 10.000 3.500 1.000 0.100 0.0

Panel L1D1-1 25 1.641Panelboard 0.208 10.000 3.500 1.000 0.100 0.0




Panel L1U 25 1.641Panelboard 0.208 10.000 3.500 1.000 0.100 0.0

Panel LRX 25 1.641Panelboard 0.208 10.000 3.500 1.000 0.100 0.0

Panel MTB 25 1.641Panelboard 0.480 10.000 3.500 1.000 0.100 0.0

The Gap and X-Factors are not utilized if the theoretically derived Lee method was used to determine the incident energy and arc flash boundary .

The Lee method is used if the bus voltage and/or short-circuit parameters are outside the range covered by the IEEE 1584 empirical equations.

SAMPLE REPORT

Location:


12.6.0CPage: 5

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Line/Cable Input Data

ID Library Size #/Phase T (°C) R

Line/Cable

Ohms or Siemens/1000 ft per Conductor (Cable) or per Phase (Line)

Adj. (ft) % Tol.

Length

YX

C-AHU1 0.6MCUN1 4/0 290.0 1 0.06300 75 0 0.0000000 0.05100

C-Baler 0.6MCUN1 10 270.0 1 1.20000 75 0 0.0000000 0.06300

C-Compactor 0.6MCUN1 10 275.0 1 1.20000 75 0 0.0000000 0.06300

C-DTA 0.6MALN1 300 235.0 2 0.07200 75 0 0.0000000 0.05100

C-H1A 0.6MALN1 250 9.0 2 0.08600 75 0 0.0000000 0.05200

C-H1P 1.0MALN1 1 12.0 1 0.25000 75 0 0.0000000 0.05700

C-L1D1-1 0.6MALN1 300 5.0 1 0.07200 75 0 0.0000000 0.05100

C-L1D1-2 0.6MALN1 300 3.0 1 0.07200 75 0 0.0000000 0.05100

C-L1D2 Line 0.6MALN1 250 3.0 2 0.08600 75 0 0.0000000 0.05200

C-L1D2 Load 0.6MALN1 250 280.0 2 0.08600 75 0 0.0000000 0.05200

C-L1D2-2 0.6MALN1 250 3.0 2 0.08600 75 0 0.0000000 0.05200

C-L1U 0.6MCUN1 6 50.0 1 0.49000 75 0 0.0000000 0.06400

C-LRX 0.6MALN1 4 160.0 1 0.51000 75 0 0.0000000 0.06000

C-MBU 0.6MCUN1 300 60.0 6 0.04500 75 0 0.0000000 0.05100

C-MTB 0.6MALN1 250 260.0 1 0.08600 75 0 0.0000000 0.05200

C-Oven(Bottom) 0.6MCUN1 2 275.0 1 0.20000 75 0 0.0000000 0.05700

C-Oven(Top) 0.6MCUN1 8 275.0 1 0.78000 75 0 0.0000000 0.06500

C-PLM 0.6MCUN1 12 5.0 1 2.00000 75 0 0.0000000 0.06800

C-Sub-Metering 0.6MCUN1 12 5.0 1 2.00000 75 0 0.0000000 0.06800

C-T1D Pri 0.6MALN1 300 9.0 1 0.07200 75 0 0.0000000 0.05100

C-UH (Vestibule) 0.6MCUN1 6 5.0 1 0.49000 75 0 0.0000000 0.06400

C-UPS1 0.6MCUN1 6 40.0 1 0.49000 75 0 0.0000000 0.06400

C-Water Heater 0.6MCUN1 2 5.0 1 0.20000 75 0 0.0000000 0.05700

Line / Cable resistances are listed at the specified temperatures.

SAMPLE REPORT

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SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

2-Winding Transformer Input Data

ID MVA Prim. kV Sec. kV % Z X/R Prim. Sec.

Transformer

% Tol.

Rating Z Variation

+ 5% - 5% % Z

Adjusted% Tap Setting

T1D 0.150 0.480 0.208 4.00 3.45 0 0 0 4.0000 2.500 2.500

Utility Transformer 0.500 12.470 0.480 4.20 5.10 0 0 0 4.2000 0 0

Impedance Input Data

ID R X Y Unit

Impedance Positive Sequence Impedanc

MSB Bus % in 0.480 kV base and 100.0 MVA base 0.01 0.01 0

% in 0.480 kV base and 100.0 MVA baseMSB Bus 2 0.01 0.01 0

SAMPLE REPORT

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SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Branch Connections

ID From Bus To Bus R X ZType

CKT/Branch % Impedance, Pos. Seq., 100 MVAbConnected Bus ID

Y

T1D B-T1D Pri 779.97 2690.91 2801.67B-T1D Sec2W XFMR

Utility Transformer B-Utility Primary 161.63 824.30 840.00B-Utility Secondary2W XFMR

C-AHU1 MSB (Distribution) 792.97 641.93 1020.23B-AHU1Cable

C-Baler MSB (Distribution) 14062.50 738.28 14081.87B-BalerCable

C-Compactor MSB (Distribution) 14322.92 751.95 14342.64B-CompactorCable

C-DTA MSB (Distribution) 367.19 260.09 449.97Panel DTACable

C-H1A MSB (Distribution) 16.80 10.16 19.63Panel H1ACable

C-H1P MSB (Distribution) 130.21 29.69 133.55Panel H1PCable

C-L1D1-1 B-T1D Sec 83.21 58.94 101.97Panel L1D1-1Cable


C-L1D2 Line B-T1D Sec 29.82 18.03 34.84Circuit Breaker L1D2Cable

C-L1D2 Load Circuit Breaker L1D2 2782.91 1682.69 3252.09Panel L1D2-1Cable


C-L1U B-UPS1 Sec 5662.91 739.65 5711.01Panel L1UCable

C-LRX Panel L1D1-1 18860.95 2218.94 18991.02Panel LRXCable

C-MBU B-Utility Secondary 19.53 22.14 29.52MSB (Main Breaker)Cable

C-MTB MSB (Distribution) 970.49 586.81 1134.10Panel MTBCable

C-Oven(Bottom) MSB (Distribution) 2387.15 680.34 2482.21B-Oven(Bottom)Cable

C-Oven(Top) MSB (Distribution) 9309.90 775.82 9342.17B-Oven(Top)Cable

C-PLM MSB (Distribution) 434.03 14.76 434.28B-PLMCable

C-Sub-Metering MSB (Distribution) 434.03 14.76 434.28B-Sub-MeteringCable

C-T1D Pri MSB (Distribution) 28.13 19.92 34.47B-T1D PriCable

C-UH (Vestibule) MSB (Distribution) 106.34 13.89 107.24B-UH (Vestibule)Cable

C-UPS1 Panel L1D2-1 4530.33 591.72 4568.81B-UPS1 PriCable

C-Water Heater MSB (Distribution) 43.40 12.37 45.13B-Water HeaterCable

MSB Bus MSB (Main Breaker) 0.01 0.01 0.01MSB (Distribution)Impedance

MSB Bus 2 MSB (Gen) 0.01 0.01 0.01MSB (Distribution)Impedance

UPS1 B-UPS1 Pri B-UPS1 SecTie Switch

SAMPLE REPORT

Location:


12.6.0CPage: 8

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Power Grid Input Data

ID ID MVASC kV R X

Rating

X/R

100 MVA Base% Impedance

Power Grid Connected Bus

Utility 12.470 164.35170 44.53977 58.727B-Utility Primary 3.69

Total Connected Power Grids (= 1 ): 58.727 MVA

SAMPLE REPORT

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Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Induction Machine Input Data

kVA kV RPM X"/R X'/R R X'X"

Induction Machine Rating X/R Ratio Machine BaseConnected Bus

IDID

% Impedance

HP/kWQty

Motors

Load AHU1 1 B-AHU1 0.480 2.07 9.66 9.66 1800 20.00 50.00 154.00 147.23

Load Baler 1 B-Baler 0.480 11.06 2.52 2.52 1800 27.83 9999.00 10.45 11.65

Load Compactor 1 B-Compactor 0.480 11.06 2.52 2.52 1800 27.83 9999.00 10.45 11.65

Total Connected Induction Motors ( = 3 ): 170.5 kVA

Lumped Load Input Data

IDID kVA kV X"/R X'/R R X'X"

Lumped Load Rating X/R Ratio % Imp. (Machine Base)

kW kvar

Loading

MTR STAT

% Load Loading

kW kvar

Lumped Load

Connected Bus

Motor Loads Static Loads

Load DTA 0.480 100 0 2.38 2.38 8.403 20.00 50.00Panel DTA 328.0 172.8 278.8 0.00 0.00

Load H1A 0.480 100 0 2.38 2.38 8.403 20.00 50.00Panel H1A 286.0 150.7 243.1 0.00 0.00

Load MTB 0.480 100 0 2.38 2.38 8.403 20.00 50.00Panel MTB 130.0 68.5 110.5 0.00 0.00

Total Connected Lumped Loads ( = 3 ): 744.0 kVA

SAMPLE REPORT

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Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

1/2 Cycle Calculation Method

Arc Flash Analysis

= 100% of base kVBase kV = 0.480

Nominal kV = 0.480

Solution Method:

Arc Fault at Bus: MSB (Distribution)

1/2 Cycle

Prefault Voltage = 100% of nominal bus kV System Grounding = Grounded

Working Distance = 24 inches

Bus Arc Flash Results

Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time

(cycles) (Seconds) (cal/cm²)

Ibf" = 16.458 FCT =Ia" = 9.536 0.050 3.0 Incident Energy = 1.001

Total Incident Energy =0.050Fault Clearing Time = 3.0 1.001

For Protective Device: CB-MBU@ Ia'' =6.729 kA

Arc Flash Boundary = 1.77 ft

Energy Level* Level 0

Arc Fault at Device

Individual Contribution

to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType

Phase Protective Device ID

CB-AHU1 LV CB3Ph 0.836 0.484 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-Baler LV CB3Ph 0.046 0.026 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-Compactor LV CB3Ph 0.046 0.026 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-DTA LV CB3Ph 1.718 0.996 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-H1A LV CB3Ph 1.582 0.917 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-H1P LV CB3Ph 0.000 0.000 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

SAMPLE REPORT

Location:


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SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.480

Solution Method:


1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time







Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType


CB-MTB LV CB3Ph 0.683 0.396 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-Oven(Bottom) LV CB3Ph 0.000 0.000 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-Oven(Top) LV CB3Ph 0.000 0.000 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-PLM LV CB3Ph 0.000 0.000 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-Sub-Metering LV CB3Ph 0.000 0.000 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-T1D LV CB3Ph 0.000 0.000 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

SAMPLE REPORT

Location:


12.6.0CPage: 12

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.480

Solution Method:


1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time







Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType


CB-UH (Vestibule) LV CB3Ph 0.000 0.000 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

CB-Water Heater LV CB3Ph 0.000 0.000 9.536 3.0 1.001CB-MBU

FCT = 1.77Total =3.0 1.001 Level 0

* NFPA 70E 2009 Table 130.7(C)(11), Protective Clothing Characteristics, is used to determine the energy level (i.e. energy range).

¨ Arcing current variation was applied at this location.

SAMPLE REPORT

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SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.480

Solution Method:

Arc Fault at Bus: MSB (Main Breaker)

1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time


Ibf" = 16.458 FCT =Ia" = 8.106 116.459 6987.5 Incident Energy = 1956.103¨


For Protective Device: Utility TX Fuse@ 85% Ia''

=0.220 kAArc Flash Boundary = 303.15 ft

Energy Level* >Max.

Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType


CB-MBU LV CB3Ph¨ 11.614 5.720 3.0 8.106 6987.5 1956.103Utility TX Fuse

FCT = 303.15Total =6987.5 1956.103 >Max.



SAMPLE REPORT

Location:


12.6.0CPage: 14

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.480

Solution Method:

Arc Fault at Bus: Panel DTA

1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time




For Protective Device: CB-DTA@ Ia'' =6.447 kA



Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType




SAMPLE REPORT

Location:


12.6.0CPage: 15

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.480

Solution Method:

Arc Fault at Bus: Panel H1A

1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time




For Protective Device: CB-H1A@ Ia'' =8.945 kA



Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType




SAMPLE REPORT

Location:


12.6.0CPage: 16

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.480

Solution Method:

Arc Fault at Bus: Panel H1P

1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time




For Protective Device: CB-H1P@ Ia'' =9.267 kA



Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType




SAMPLE REPORT

Location:


12.6.0CPage: 17

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.208

Solution Method:

Arc Fault at Bus: Panel L1D1-1

1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time




For Protective Device: CB-T1D@ Ia'' =1.558 kA



Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType


CB-L1D1 LV CB3Ph 7.626 3.596 244.7 3.596 1.5 0.275CB-T1D

FCT = 0.61Total =1.5 0.275 Level 0

CB-LRX LV CB3Ph 0.000 0.000 3.596 1.5 0.275CB-T1D

FCT = 0.61Total =1.5 0.275 Level 0



SAMPLE REPORT

Location:


12.6.0CPage: 18

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.208

Solution Method:


1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time




For Protective Device: CB-T1D@ Ia'' =1.544 kA



Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType




SAMPLE REPORT

Location:


12.6.0CPage: 19

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.208

Solution Method:


1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time




For Protective Device: CB-L1D2@ Ia'' =2.424 kA



Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType


CB-L1U LV CB3Ph 0.000 0.000 2.424 1.5 0.179CB-L1D2

FCT = 0.47Total =1.5 0.179 Level 0



SAMPLE REPORT

Location:


12.6.0CPage: 20

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.208

Solution Method:


1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time




For Protective Device: CB-L1D2@ Ia'' =2.416 kA



Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType




SAMPLE REPORT

Location:


12.6.0CPage: 21

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.208

Solution Method:

Arc Fault at Bus: Panel L1U

1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time




For Protective Device: CB-L1D2@ 85% Ia'' =1.109 kA



Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType




SAMPLE REPORT

Location:


12.6.0CPage: 22

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.208

Solution Method:

Arc Fault at Bus: Panel LRX

1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time




For Protective Device: CB-LRX@ 85% Ia'' =0.901 kA



Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType




SAMPLE REPORT

Location:


12.6.0CPage: 23

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal


Arc Flash Analysis


Nominal kV = 0.480

Solution Method:

Arc Fault at Bus: Panel MTB

1/2 Cycle




Total Bolted

(kA)

Total Arcing

(kA)

Fault Clearing Time




For Protective Device: CB-MTB@ Ia'' =4.664 kA



Arc Fault at Device


to Bus Arc Fault

(kA) (kA)

Incident Energy

FCT

(cycles)

ArcingBolted Arcing

(kA)

FCT

(cycles)

Incident E

(cal/cm²) Level*

Energy

(ft)

AFB

TypeID for FCTType




SAMPLE REPORT

Location:


12.6.0CPage: 24

SN: PCX-CORP01

Engineer: XX

Filename: PCXXXXX


Contract:

City, ST

PCXXXXX

Date: XX-XX-2016

Revision: Base

Config.: Normal

Incident Energy Summary

Bus

Total Fault

Current (kA)

Bolted Arcing

Arc-Flash Analysis Results

(cycles)

FCT

(cal/cm²)

Incident E

Level

Energy

(ft)TypeNom. kVID

AFB

MSB (Distribution) 0.480 16.458 9.536 1.001 1.77Switchboard Level 03.000

MSB (Main Breaker) 0.480 16.458 8.106 1956.103 303.15Switchboard >Max.6987.547

Panel DTA 0.480 11.895 7.605 0.647 1.03Panelboard Level 01.572

Panel H1A 0.480 16.209 9.906 0.822 1.19Panelboard Level 01.500

Panel H1P 0.480 14.991 9.267 0.765 1.14Panelboard Level 01.500

Panel L1D1-1 0.208 7.626 3.596 0.275 0.61Panelboard Level 01.500




Panel L1U 0.208 1.800 1.109 0.118 0.36Panelboard Level 02.291

Panel LRX 0.208 1.338 0.901 3.864 3.06Panelboard Level 194.224

Panel MTB 0.480 7.508 5.134 0.404 0.77Panelboard Level 01.500

Working

Distance

Arc Flash

Boundary

Incident

Energy Energy

Level(inches)(ft)

FCT

(cycle)

Open

(cycle)

PD Arc

Fault (kA) (cal/cm²)

Trip

(cycle)

Bolted Fault (kA)Gap

(mm) Source Trip Device IDPDBusEquip. TypeID Nom. kV

Trip DeviceFaulted Bus Fault Current

Summary - Arc Flash Hazard Calculations

MSB (Distribution) 0.480 Switchboard 32 16.458 6.729 CB-MBU 3.00 0.00 1.8 1.0 24 3.00 11.614 Level 0

MSB (Main Breaker) 0.480 Switchboard 32 16.458 0.220 Utility TX Fuse 6987.55 0.00 303.2 1956.1 24 6987.55 0.447 >Max.

Panel DTA 0.480 Panelboard 25 11.895 6.447 CB-DTA 1.57 0.00 1.0 0.6 18 1.57 10.084 Level 0

Panel H1A 0.480 Panelboard 25 16.209 8.945 CB-H1A 1.50 0.00 1.2 0.8 18 1.50 14.635 Level 0

Panel H1P 0.480 Panelboard 25 14.991 9.267 CB-H1P 1.50 0.00 1.1 0.8 18 1.50 14.991 Level 0

Panel L1D1-1 0.208 Panelboard 25 7.626 1.558 CB-T1D 1.50 0.00 0.6 0.3 18 1.50 3.305 Level 0

Panel L1D1-2 0.208 Panelboard 25 7.525 1.544 CB-T1D 1.50 0.00 0.6 0.3 18 1.50 3.261 Level 0

Panel L1D2-1 0.208 Panelboard 25 4.350 2.424 CB-L1D2 1.50 0.00 0.5 0.2 18 1.50 4.350 Level 0

Panel L1D2-2 0.208 Panelboard 25 4.328 2.416 CB-L1D2 1.50 0.00 0.5 0.2 18 1.50 4.328 Level 0

Panel L1U 0.208 Panelboard 25 1.800 1.109 CB-L1D2 2.29 0.00 0.4 0.1 18 2.29 1.800 Level 0

Panel LRX 0.208 Panelboard 25 1.338 0.901 CB-LRX 94.22 0.00 3.1 3.9 18 94.22 1.338 Level 1

Panel MTB 0.480 Panelboard 25 7.508 4.664 CB-MTB 1.50 0.00 0.8 0.4 18 1.50 6.822 Level 0

SAMPLE REPORT




Appendix F: Equipment labels

SAMPLE REPORT

Arc Flash and Shock Hazard PresentAppropriate PPE Required

V-rating 500 VACClass 00 Insulating Gloves

Equipment MSB (Distribution)

Prohibited Approach Boundary ft0.1Restricted Approach Boundary ft1.0Limited Approach Boundary ft3.5

Shock Hazard Exposure 480 VAC

Working Distance 24.0 inPPE Requirements have not been approved

Incident Energy (Ed) 1.0 cal/cm² Arc Flash Boundary (Dc) 1.8 ft

Shock Hazard when covers removed

Source protective Device CB-MBU

Level 0

Min. PPE Requirements

02-11-2016



Equipment MSB (Main Breaker)



Working Distance 24.0 inIncident Energy (Ed) 1956.1 cal/cm² Arc Flash Boundary (Dc) 303.2 ft


Source protective Device Utility TX Fuse

Exceeds Max. PPE Arc Rating

02-11-2016



Equipment Panel DTA






Source protective Device CB-DTA

Level 0


02-11-2016



Equipment Panel H1A






Source protective Device CB-H1A

Level 0


02-11-2016

SAMPLE REPORT



Equipment Panel H1P






Source protective Device CB-H1P

Level 0


02-11-2016



Equipment Panel L1D1-1






Source protective Device CB-T1D

Level 0


02-11-2016









Source protective Device CB-T1D

Level 0


02-11-2016









Source protective Device CB-L1D2

Level 0


02-11-2016

SAMPLE REPORT










Level 0


02-11-2016



Equipment Panel L1U







Level 0


02-11-2016



Equipment Panel LRX






Source protective Device CB-LRX

Level 1


02-11-2016



Equipment Panel MTB






Source protective Device CB-MTB

Level 0


02-11-2016

SAMPLE REPORT




Appendix G: Reference Documents