overhead 345 kv transmission line design process a …

OVERHEAD 345 KV TRANSMISSION LINE DESIGN PROCESS

ANALYTICAL & PRACTICAL SOLUTIONS

A Project

Presented to the faculty of Department of Electrical and Electronic Engineering

California State University, Sacramento

Submitted in partial satisfaction of

the requirements for the degree of

MASTER OF SCIENCE

in

Electrical and Electronic Engineering

by

RK Ravuri

Alexander Takahashi

FALL

2015

ii

OVERHEAD 345 KV TRANSMISSION LINE DESIGN PROCESS


A Project

by

RK Ravuri

Alexander Takahashi

Approved by:

, Committee Chair

Mahyar Zarghami, Ph.D.

, Second Reader

Fethi Belkhouche, Ph.D.

Date

iii

Students: RK Ravuri

Alexander Takahashi

I certify that these students have met the requirements for the format contained in the

University format manual and that this project is suitable for shelving in the Library and

that credit is to be awarded for this project.

, Graduate Coordinator

B. Preetham. Kumar, Ph.D. Date

Department of Electrical and Electronic Engineering

iv

Abstract

of

OVERHEAD 345KV TRANSMISSION LINE DESIGN PROCESS


by

RK Ravuri and Alexander Takahashi

The industry and technology of high-voltage alternative current (HVAC) transmission

lines have evolved over 100 years in the United States and many parts of the world,

requiring new engineering and economical solutions. This report presents some of the

critical aspects of transmission line evaluation, design, and physical installation of a

typical 345 kV cross-country transmission line in the United States, with some degree of

commonality to other technical standards in the rest of the world. The project will also

examine theoretical aspects of transmission system design criteria such as power flow

analysis, short circuit and relay coordination and more basic parameters such as trans-

mission efficiency, voltage regulation, plan and profile for an overhead transmission

line.

The analytical part of the transmission system study was performed using the MATLAB

program and the practical design was developed using the PLS-CADD program widely

used by utility and power engineering companies worldwide. The study also includes a

review of special construction method, used in building a HV transmission line over a

rugged terrain, which requires special equipment, tools and skilled construction

personnel.

, Committee Chair

Mahyar Zarghami, Ph.D.

Date

v

TABLE OF CONTENTS

Page

List of Tables ....................................................................................................................... vii

List of Figure....................................................................................................................... viii

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

2. LITERATURE SURVEY ....................................................................................... 4

2.1 Concept of a Typical Transmission line ........................................................ 4

2.2 Planning ......................................................................................................... 7

2.3 Engineering .................................................................................................. 7

2.4 Certification .................................................................................................. 9

2.5 Design & Construction ............................................................................... 10

3. ANALYTICAL ANALYSIS: MATHEMATICAL MODEL .............................. 14

3.1 Transmission Line Parameters .................................................................... 14

3.2 Single Line-to-Ground Fault ....................................................................... 16

3.3 Double Line-to-Ground Fault ..................................................................... 18

3.4 Line-to-Line Fault ....................................................................................... 22

3.5 Three-Phase Fault ........................................................................................ 24

3.6 Corona Loss ................................................................................................ 33

4. TRANSMISSION LINE DESIGN ....................................................................... 35

4.1 Design Criteria ............................................................................................. 35

4.2 Route Selection ............................................................................................. 36

vi

4.3 Reconnaissance and Preliminary Survey ..................................................... 37

4.4 Drawings ...................................................................................................... 37

4.5 Permits .......................................................................................................... 39

5. CONSTRUCTION METHODS ........................................................................... 40

5.1 Equipment and Material .......................................................................... 40

5.2 Special Construction Equipment .............................................................. 40

5.3 Conductor Blocks ..................................................................................... 41

5.4 Conductor Installation .............................................................................. 41

5.5 Construction Techniques .......................................................................... 41

6. INFRASTRUCTURE REGULATION AND SECURITY TRENDS ................. 45

7. CONCLUSIONS .................................................................................................. 48

Appendix A. Plan & Profile Report (Partial) ........................................................... 50

Appendix B. PLS-CADD Load Cases Report .......................................................... 55

Appendix C. H-Frame Structure Design .................................................................. 61

Appendix D. Sag & Tension Report-Conductors ..................................................... 62

Appendix E. Sag & Tension Report-Shield Wire .................................................... 64

Appendix F. Transmission Line Route (3-D) Partial ............................................... 66

Appendix G. ASPEN Program – Fault Analysis ...................................................... 67

Appendix H. MATLAB Program ............................................................................ 69

References .................................................................................................................. 80

vii

LIST OF TABLES

Tables Page

3.1 Efficiency and Voltage Regulation..................................................................... 27

viii

LIST OF FIGURES

Figures Page

Figure 2.1 Flow diagram of HVAC Transmission Line ..................................... 6

Figure 2.2 Typical Double-Circuit Transmission Tower Designs ..................... 12

Figure 3.1 Typical Structure Configuration ........................................................16

Figure 3.2 Physical Connections for Single Line-to-Ground Fault ................... 17

Figure 3.3 Positive, Negative, Zero Sequence Interconnection for

Single Phase Line-to-Ground Fault .................................................. 17

Figure 3.4 Physical Connections for Double

Line-to-Line-to-Ground Fault .......................................................... 19

Figure 3.5 Positive, Negative and Zero Sequence Interconnections for

Double Line-to-Ground Fault ........................................................... 20


Double Line-to-Ground Fault Through Zero Impedance.................. 21

Figure 3.7 Physical Connections for Line-to-Line Fault ................................... 22

Figure 3.8 Positive, Negative and Zero Sequence Interconnections

for Line-to-Line Fault ....................................................................... 23

Figure 3.9 Physical Connection Diagram for a Three-Phase Fault.................... 25

Figure 3.10 Positive, Negative and Zero Sequence

Interconnections for Three-Phase Fault............................................. 25

ix

Figure 5.1: Transmission Line Construction-River Crossing.............................. 43

Figure 5.2: Transmission Line Construction -Rugged Terrain ........................... 43

Figure 5.3: Transmission Line Construction - Aerial ........................................ 43

Figure 5.4: Transmission Line Mode of Construction by Air ............................44

Figure 5.5: Transmission Line Construction Overhead

Model of a Tower ........................................................................... 44

1

Chapter 1

INTRODUCTION

DESIGNING OF HVAC TRANSMISSION LINE:

The task of designing a HVAC transmission line has a number of factors to consider

such as planning, survey and design. This report presents the results of the detail design

of a cross-country overhead 345 kV transmission line of approximately 168 miles in

length in Southern California. The starting point of the transmission line is Bishop,

California and the termination point at Kramer Junction along the Highway 395. This

design takes into consideration the ability to transmit power over the distance

economically, and satisfies electrical and mechanical requirements. Our goal is to

design the 345 kV transmission line for the given power factor, over a given distance,

and be within limits of given regulations, efficiency and losses.

In this project, we also discuss power system analysis, which evaluates voltages and line

currents at various fault locations. These faults are identified as balanced and

unbalanced faults. The unbalanced faults are single line-to-ground, line-to-line and

double line-to-ground faults. A balanced fault occurs in a three-phase system, where all

three phases are subjected to the fault simultaneously. The fault analysis is necessary to

design the protection system set-up using relays where three phase balanced fault data

are needed to set-up the phase relays. Line to ground fault data are used to set-up

ground relays. Fault analysis data are necessary to compute the maximum amount of

current the system might experience under fault conditions so the appropriate equipment

2

is selected to protect from damage. The most common faults, which occur in practice,

are unbalanced faults, which involve at least one conductor coming into contact with

another conductor or with ground through impedance. The single line-to ground fault is

the most common, and the second most common fault is double line to ground fault.

The least common fault is three phase-balanced fault.

The fault analysis is performed by using the symmetrical components method. This

method allows expressing three unbalanced sets of phasors into three sets of balanced

phasors. In fault analysis, the system is considered as balanced to the point where it is

necessary to calculate fault currents that is imperative for protection and design

purposes. The causes of faults vary and occur due to lightning, falling trees, snow, ice

and animals. A line fault causes a change in the integrity of the network, and lightning

causes induced transient peak voltages that are the most common in electrical system.

The insulator flashover conditions during stormy weather causes 75% of electrical

faults. This creates overcurrent conditions in the electrical system that can cause

damage to equipment such as transformers, capacitor banks, voltage regulators, etc.

Rough weather and stormy conditions cause the trees to fall on power lines and result in

a fault. This is the reason why fault analysis is an important factor of electrical power

engineering.

In addition to the technical aspects of transmission system analysis, the report addresses

the planning and execution of the type of cross-country overhead transmission line in the

3

current regulatory environment and smart-grid technology application. Although the

regulations may vary from location and countries, the new trend in regulating and

permitting transmission lines is becoming the key element of electrical infrastructure

development in most of industrial regions.

The other aspect of transmission system growth is the smart grid technologies

application to facilitate load growth and infrastructure security. This report provides

overview of these technologies and the trend in power grid security.

4

Chapter 2

LITERATURE SURVEY

2.1 Concept of a Typical Transmission line

A typical transmission line project in the Unites States and many other countries or

regions undergoes an established process, which includes:

(a) Planning

(b) Engineering

(c) Certification

(d) Design & Construction

Each of these steps have sub-phases which are also standard or well defined in many

cases and projects. This report will address each of these major phases in sufficient

detail to provide a roadmap for a typical cross-country overhead transmission line

serving major load centers or regional networks. Using overhead transmission lines is

the most efficient and economical way of transporting large amounts of electricity.

These HVAC lines are operated by utilities or regional system operation organizations,

such as Independent System Operators (ISO). With the goal of ensuring grid reliability –

that there is enough electricity ready and available to meet demand at all hours – the

system planners or independent power producers (IPPs) forecast the capacity of the

transmission over many years ahead. These forecasts lead to technical and economic

studies required for siting, permitting, and environmental assessments and funding of

each transmission line option.

5

This report examines the steps required to plan and implement a typical cross-country

transmission line project in the State of California as an example from the above-

mentioned process. The location, routing, design and construction of this hypothetical

345 kV transmission line are modeled based on actual terrain on the east side of Sierra

Mountain range between Bishop and Kramer Junction for a 200 MW load.

To illustrate a typical process for planning, engineering, certification and implementing

this type of transmission line, we provide a process flow diagram below for reference

only.

6

Figure 2.1 Flow diagram of HVAC Transmission Line

7

The design steps of a typical transmission line are briefly described below:

2.2 Planning

Typical cross-county overhead transmission line projects undergo the following major

steps:

(a) Determining the need for a new line to service regional or specific loads

(b) Engineering, routing and environmental assessment

(c) Cost Assessment and Financial Packaging

This stage of the project involves a great deal of load studies, marketing surveys,

conceptual technical and economic studies and investment research. The front-end

engineering also accompanies environment studies and broad-brush assessment as a

prelude to raising funding or public support. The public support of any cross-country

transmission lines will also require Assessment & Application for a Certificate of

Convenience and Necessity and Post-approval and pre-construction.

2.3 Engineering

In this stage of the project, the proposed cross-country transmission line undergoes

critical technical study which includes modeling and basic design criteria for the

transmission line studies for this project, described below. It covers the basic theory of

transmission AC power over the long overhead power line and practical aspects of the

line derived from these theories. Specifically, the following key parameters of a HVAC

transmission line are applied in the analytical study and physical design of a radial

transmission line:

8

(a) Load flow characteristics

(b) Short circuit conditions

(c) Dynamic response of the line

(d) Voltage regulation limits

(e) Transmission line efficiency

The performance and dynamic response of the transmission line are analyzed using

MATLAB program.

The input data for both of these computer-based programs is discussed in this report and

also listed in Chapter 3 of this project report.

The line modeling also includes the following input parameters:

Conductor size and physical property

(a) Line constants

(b) Circuit configuration

(c) Line spacing

(d) Type of structures

(e) Impedance parameters

9

2.4 Certification

One of the major steps in building a cross-country transmission line is the certification

and siting procedures required by the government agencies, which in the United States is

governed by the Federal Energy Regulatory Commission (FERC).

Accordingly, the 345 kV transmission line project designed in this report and processed

in the manner dictated by FERC through the application process that will include the

comprehensive planning, regulatory review and compatibility with national energy

policies.

This regulatory process also involves regional, state and local community review and

comments to ensure that the proposed transmission lines are safe, environmentally

acceptable and serve public interest. It also entails review of the transmission line

project for sound technical and economic merits with emphasis on network reliability,

safety and security.

This information as well as information necessary for FERC to complete a thorough

environmental analysis is the basis of the information required by the application.

FERC regulations require an extensive pre-filing process to facilitate issue identification

and resolution, to facilitate maximum participation from all stakeholders, and to provide

all interested entities with timely and accurate project information to base their

comments and recommendations.

10

2.5 Design & Construction

Line Construction:

The physical design of the transmission line is based on acceptable industry standards

and regulators codes and regulations applicable to the route of the transmission line

projects.

The design of a typical cross-country transmission lines in various terrains includes the

following steps:

(a) Detailed map and topography study

(b) Detailed transmission route survey using Global Positioning System (GPS)

survey equipment and location of points of inflection (PIs).

(c) Geotechnical (soils) testing of selected tower sites.

(d) Detailed engineering plans of electrical characteristics of the transmission line,

such as conductor size, type of tower selection, sag and tension analysis, etc.

(e) Detailed transmission lines design using PLS-CAD program

(www.powline.com) and other applicable regulatory and industry standards and

specification for rugged terrain construction, including sag & tension, clearances

and structure design

(f) Plan & Profile drawings that provide all the critical information for line

construction.

(g) Development of equipment and material specifications

(h) Development of construction specifications

(i) Preparation of detailed Bill of Material & list of special equipment

11

Selection of Structure and Design Spans:

In the initial design, the tower and structures selected based on suitability and cost

effective for the given terrain. As an example, the following typical transmission

structures, shown in Figure 2.2 below considered for the final selection:

The key features of typical towers shown in Figure 2.2 below are:

Figure 2.2(a) Conventional steel lattice tower - the most cost-effective compact

configuration

Figure 2.2(b) Mono-Pole Steel pole tower - offers the best compaction and narrow

ROW

Figure 2.2(c) Portal Steel Tower – offers best compaction with all phases inside of

tower

Figure 2.2(d) Low-Profile Portal Steel Tower – offers a lower in height and reduced

visual impact

12

(a) (b) (c) (d)

Figure 2.2 Typical Double-Circuit Transmission Tower Designs

Conductor Selection:

The conductor type and size are selected based on projected current load the line is

expected to carry in and the site conditions encountered along the length of the line,

including topography, meteorological conditions and elevation. The most common types

of conductors used for cross-country AC lines is Aluminum Conductor Steel Reinforced

(ACSR) conductors that consist of a solid or stranded steel core surrounded by strands of

aluminum.

The key advantage of ACSR is high tensile strength so that they are used for longer

spans with less supports, and better performance with respect to corona limitations.

13

Working & Regulatory Clearances:

The cross-county overhead transmission lines are required to maintain clearance

between the live conductors and the earth (ground), vegetation, structures, roads,

highways, and other objects to maintain safe and reliable operation of the line.

Such working clearances are governed by various regulatory agencies in California and

other states, by such rules as General Order 95, National Electric Safety Code (NESC)

and Occupational Safety and Health Administration (OSHA). In California, the working

clearance are governed by rules prescribed in the California General Order (G.O. 95) for

design and construction of transmission and distribution lines.

The other codes and regulations that could apply with respect to working or regulatory

clearance for a cross-country overhead transmission lines include the following:

Public Resource Code 4292 - Firebreak Clearing

(http://www.weblaws.org/california/codes/ca_pub_res_section_4292)

Public Resource Code 4293 - State Responsibility

(http://www.weblaws.org/california/codes/ca_pub_res_section_4293)

General Order 95 - Utility Vegetation Management Requirements

(http://www.cpuc.ca.gov/gos/GO95/go_95_rule_35.html)

North American Electric Reliability Council (NERC) Standard FAC-003-1 -

Transmission Vegetation Management Standard (http://www.nerc.com/files/fac-003-1)

http://www.pge.com/myhome/customerservice/other/treetrimming/lawsregulations/#publicresourcecodesection4292powerlinehazardreduction

http://www.weblaws.org/california/codes/ca_pub_res_section_4292

http://www.pge.com/myhome/customerservice/other/treetrimming/lawsregulations/#publicresourcecodesection4293lineclearanceguidelines

http://www.weblaws.org/california/codes/ca_pub_res_section_4293

http://www.pge.com/myhome/customerservice/other/treetrimming/lawsregulations/#generalorder95rule35treepruning

http://www.cpuc.ca.gov/gos/GO95/go_95_rule_35.html

http://www.nerc.com/files/fac-003-1

14

Chapter 3

ANALYTICAL ANALYSIS: MATHEMATICAL MODEL

3.1 Transmission Line Parameters

The input data used for calculations are summarized below for a long transmission line.

This project study was performed using MATLAB and EDSA Design Base computer-

based programs with a hypothetical route, load and generation and a collection of

commercially available mapping data.

Transmission Line Constants

Project Name: 345 kV Overhead Transmission Line: EEE-500 Graduate Project

System Voltage: 345 kV, 3-Phase, 60 Hz

Length: 168 miles (270.4 km)

Structures: Tower # 3H2 (Shown in Figure 1)

Conductors: 397.5 kcmil 26/7 Strands ACSR (“Ibis”)

Load: 200 MW

Physical Conditions

Earth Resistivity = 100.00 (ohm-meter)

Average Height Calculation = Method 1

Transposition = Yes

Circuit Name = C1

From = Bus 1

To = Bus 2

15

Target Performance

Voltage Regulation: Less Than 5%

Efficiency: Greater than 95%

Conductor Selection

Conductors: 200 mm2 ACSR (“Jaguar”)

Equivalent to 397.5 kcmil 26/7 Strands ACSR (“Ibis”)

Conductor per Phase: Single (1 conductor per phase)

Structure Configuration: Per sketch below

16

Figure 3.1 Typical Structure Configuration

3.2 Single Line-to-Ground Fault

Usually one of the most general faults in power system is single line to ground fault.

In such a case, out of three phases only one single phase is grounded through some

impedance. The physical connections of this type of fault can be represented as

Figure 3.2.

17

Figure 3.2 Physical Connections for Single Line-to-Ground Fault

The following terminal conditions can be derived from the diagram above.

Ib = Ic = 0

Ia = If

Ea = IaZF

The phase to ground fault is represented by three sequences network diagrams connected

in series together as shown in Figure 3.3 below.

Figure 3.3 Positive, Negative, Zero Sequence Interconnections for Single- Phase

Line-to-Ground Fault

18

By applying the Ohm’s Law, we can derive the following equation.

Ia0 = Ia1 = Ia2 = 1Ð0°

𝑍0+𝑍1+𝑍2+𝑍𝑓

We use matrix equation to solve for the fault-line currents from the sequence currents as

follows:

[𝐼𝑎𝐹

𝐼𝑏𝐹

𝐼𝑐𝐹

] = [1 1 11 𝑎2 𝑎 1 𝑎 𝑎2

] [𝐼𝑎0

𝐼𝑎1

𝐼𝑎2

]

Phase b and c fault currents are zero since they are not faulted. A fault current can be

expressed as follows:

IaF = Ia0 + Ia1 + Ia2 = 3Ia0

Sequence voltages for the fault shown in Figure 3.3 are expressed below for positive,

negative and zero sequences:

Va0 = -Z0Ia0

Va1 = VF – Z1Ia1

Va2 = -Z2Ia2

The actual fault voltages can be found after we determine sequence voltages as follows:

[𝑉𝑎𝐹

𝑉𝑏𝐹

𝑉𝑐𝐹

] = [1 1 11 𝑎2 𝑎

1 𝑎 𝑎2 ] [

𝑉𝑎0

𝑉𝑎1

𝑉𝑎2

]

3.3 Double Line-to-Ground Fault

Double line to ground fault occurs when two lines are shorted through some impedance

to the ground. A general physical diagram of double line to ground fault connections is

shown in Figure 3.4 below.

19

Figure 3.4 Physical Connections for Double Line-to-Line-to-Ground Fault

The following terminal conditions could be derived by looking at Figure 3.4 which

depicts physical connections that occur during the fault:

IaF = 0

VbF = IbFZF + Zg(IbF + IcF)

VcF = IcFZF + Zg(IbF + IcF)

Double line-to-ground is represented by three sequence network diagrams connected

together as shown in Figure 3.5 below.

20

Figure 3.5 Positive, Negative and Zero Sequence Interconnections for Double

Line-to-Ground Fault

Positive sequence current can be calculated as follows:

0

12 0

1

2 0

1.0 0I

( )( 3 )

( ) ( 3 )

af f g

f

f f g

Z Z Z Z ZZ Z

Z Z Z Z Z

Ð

Negative and zero sequence currents can be calculated by using the following equations:

0

2 2

2 0

( 3 )I I

( ) ( 3 )

f g

a a

f f g

Z Z Z

Z Z Z Z Z

2

0 1

2 0

( )I I

( ) ( 3 )

f

a a

f f g

Z Z

Z Z Z Z Z

21

This could be further simplified by expressing the sequence currents with the assumed

fault impedance and zero ground impedance. The modified sequence network diagram

for the fault is shown in Figure 3.6 below.

Figure 3.6 Positive, Negative and Zero Sequence Interconnections for Double Line-

to-Ground Fault Through Zero Impedance

0

10 2

1

0 2

1.0 0Ia Z Z

ZZ Z

Ð

02 1

0 2

I Ia a

Z

Z Z

20 1

0 2

I Ia a

Z

Z Z

The actual fault currents could be obtained by using the matrix equation as shown

below:

[𝐼𝑎𝐹

𝐼𝑏𝐹

𝐼𝑐𝐹

] = [1 1 11 𝑎2 𝑎 1 𝑎 𝑎2

] x [𝐼𝑎0

𝐼𝑎1

𝐼𝑎2

]

22

The sequence networks fault voltages described by the following equations were derived

by inspecting Figure 3.6 above.

Va0 = -Z0Ia0

Va1 = 1- Z1Ia1

Va2 = -Z2Ia2

The fault voltages for each phase could be derived by using the following equation:

[𝑉𝑎𝐹

𝑉𝑏𝐹

𝑉𝑐𝐹

] = [1 1 11 𝑎2 𝑎

1 𝑎 𝑎2 ] x [

𝑉𝑎0

𝑉𝑎1

𝑉𝑎2

]

3.4 Line-to-Line Fault

These faults occur when two phases are shorted with each other, which usually results

from the presence of trees. A general physical diagram of line-to-line fault connections

is shown in Figure 3.7 below.

Figure 3.7 Physical Connections for Line-to-Line Fault

The following terminal equations can be derived by inspecting Figure 3.7 above.

23

afI 0

bF cFI I

bc b c F bFV V V Z I

The sequence diagrams for positive, negative and zero sequence networks are shown in

Figure 3.8 below.

Figure 3.8 Positive, Negative and Zero Sequence Interconnections for a Line-to-

Line Fault

By examining Figure 3.8 above, the following equations can be derived for the sequence

currents.

a0I 0

1 2I Ia a

1 2

f

f

V

Z Z Z

Now using sequence currents, we can find out the expressions for line fault currents as

follows:

24

[𝐼𝑎𝐹

𝐼𝑏𝐹

𝐼𝑐𝐹

] = [1 1 11 𝑎2 𝑎 1 𝑎 𝑎2

] x [𝐼𝑎0

𝐼𝑎1

𝐼𝑎2

] = [1 1 11 𝑎2 𝑎 1 𝑎 𝑎2

] x [

0𝐼𝑎1

−𝐼𝑎1

]

Fault line currents are expressed below:

I 0af

1I 3Ibf aj

1I 3Ibf aj

The sequence voltages for the sequence networks can be found by inspecting Figure 3.8.

a0V 0

a1 1 a1V 1 – Z I

a2 2 a2 2 a1V Z I Z I

The fault voltages for each phase could be derived by the following equation:

[𝑉𝑎𝐹

𝑉𝑏𝐹

𝑉𝑐𝐹

] = [1 1 11 𝑎2 𝑎

1 𝑎 𝑎2 ] x [

𝑉𝑎0

𝑉𝑎1

𝑉𝑎2

]

3.5 Three-Phase Fault

These faults occur when three phases are shorted with each other. A three-phase fault

connection diagram is shown in Figure 3.9 below.

25

Figure 3.9 Physical Connection Diagram for a Three-Phase Fault.

The sequence diagram for positive, negative and zero sequences are shown in Figure

3.10 below.


Three-Phase Fault.

By inspecting the above diagram, we could derive these equations:

a0I 0

a2I 0

26

1

1

If

a

f

V

Z Z

Now using sequence currents, we can find the expressions for line fault currents as

follows:

[𝐼𝑎𝐹

𝐼𝑏𝐹

𝐼𝑐𝐹

] = [1 1 11 𝑎2 𝑎 1 𝑎 𝑎2

] x [0

𝐼𝑎1

0]

The fault line currents are then expressed as follows:

1

If

af

f

V

Z Z

0

2

1

1

240I I

f

bf a

f

Va

Z Z

Ð

0

1

1

120I I

f

cf a

f

Va

Z Z

Ð

The following sequence voltages for the sequence networks can be found by inspecting

Figure 3.10 above.

a0V 0

a1 a1V Z If

a2V 0

The fault voltages for each phase can be derived as follows:

[𝑉𝑎𝐹

𝑉𝑏𝐹

𝑉𝑐𝐹

] = [1 1 11 𝑎2 𝑎 1 𝑎 𝑎2

] x [𝑉𝑎0

𝑉𝑎1

𝑉𝑎2

] = [1 1 11 𝑎2 𝑎

1 𝑎 𝑎2 ] [

0 𝑍𝐹𝐼𝑎1

0] = [

𝑍𝐹𝐼𝑎1

𝑍𝐹𝐼𝑎1Ð240° 𝑍𝐹𝐼𝑎1Ð120°

]

27

To simplify the process of selecting an optimum transmission line conductor, the authors

designed MATLAB software to calculate the Efficiency and voltage regulation as shown

in table 3.1 below.

Table 3.1 Efficiency and Voltage Regulation

Conductor

Type

& Size

Aluminum/

Steel

Resistance Inductance

reactance

Capacitance

reactance

Efficiency Voltage

regulation

Current

amps

Circular

Mils

Strands Ra Xa X'a % %

636,000 30/19 0.1618 0.406 0.0937 98.2784 1.6234 780

605,000 54/7 0.1775 0.417 0.0957 98.1355 1.4972 750

605,000 26/7 0.172 0.415 0.0953 98.1884 1.5389 760

556,500 26/7 0.1859 0.42 0.0965 98.0574 1.4281 730

556,500 30/7 0.1859 0.415 0.0957 98.0485 1.4347 730

500,000 30/7 0.206 0.421 0.0973 97.8602 1.2744 690

477,000 26/7 0.216 0.43 0.0988 97.7768 1.1938 670

477,000 30/7 0.216 0.424 0.098 97.7668 1.1974 670

397,500 26/7 0.259 0.441 0.1015 97.3812 0.8654 590

397,500 30/7 0.259 0.435 0.1006 97.3684 0.8719 600

336,400 26/7 0.306 0.451 0.1039 96.9548 0.5155 530

336,400 30/7 0.306 0.445 0.1032 96.9436 0.5168 530

300,000 26/7 0.342 0.458 0.1057 96.6361 0.2467 490

28

To maintain the percentage of voltage regulation less than 5%, and the transmission line

efficiency less than 95% it was decided to use the 300kcmil 26/7 ACSR conductor. It

also has current capacity of 490 amps, which provides ample capacity for 200 MW load

and offers additional capacity for the future growth.

The design parameters for the transmission line studies in the Project are summarized as

follows: (See Reference [1])

𝑟𝑎 = 0.342 Ω 𝑚𝑖𝑙𝑒⁄

𝑥𝑎 =0.458Ω𝑚𝑖𝑙𝑒⁄ 𝑥𝑑 = 0.3773Ω

𝑚𝑖𝑙𝑒⁄

𝑥𝑎′ = 0.1057MΩ

𝑚𝑖𝑙𝑒⁄ 𝑥𝑑′ =0.0922MΩ

𝑚𝑖𝑙𝑒⁄

The inductive reactance is

𝑥𝐿 = 𝑥𝑎 + 𝑥𝑑 = 0.458+0.3773= 0.8353Ω𝑚𝑖𝑙𝑒⁄

The capacitive reactance is

𝑥𝐶 =𝑥𝑎′ + 𝑥𝑑

′ = 0.1057+ 0.0922= 0.1979 𝑀 Ω𝑚𝑖𝑙𝑒⁄

To find the ABCD constants of the line with the 168 miles long line, we need to find the

propagation constant and the characteristic impedance of the line.

The impedance per mile, z is

z = 𝑟𝑎 + 𝑗𝑥𝐿 = 0.342 +j0.8353= 0.9026Ð67.7342°

The admittance per mile, y is

y = j1

𝑥𝐶 = j5.053 = 5.053 x 10−6 Ð90° S 𝑚𝑖𝑙𝑒⁄

The propagation constant of the line per mile is

29

g = √zy = √(0.775 Ð81.63°) x (5.518 x 10−6 Ð90°) = 2.1x10−3Ð78.8671°

The propagation constant of the line with the line length of 168 miles is calculated as

follows:

g(ℓ) = (2.068x10−3Ð85.81°) x (178) = 0.3417Ð78.8671°

The characteristic impedance of the line can be calculated as follows:

𝑍𝐶 = √z

y = √

(0.775 Ð81.63°)

(5.518 x 10−6 Ð90°) = 422.6404Ð-11.1329°

The characteristic admittance of the line is

𝑌𝐶 = 1

𝑍𝐶 =

1

(422.6404Ð−11.1329°)

The line constant ABCD can be calculated with the parameters above. The line constant

A can be calculated by using the following hyperbolic functions:

A = cosh gℓ = cosh (0.3417Ð78.8671°) = 0.9464 + j0.0217 = 0.9466 Ð1.3150°

The line constant B can be calculated as follows:

B = 𝑍𝐶 sinh gℓ = (422.6404Ð-11.1329°) sinh (0.3417Ð78.8671°) =

141.8311 Ð68.1597°

The line constant C can be computed as follows:

C = 𝑌𝐶 sinh gℓ = (1

(422.6404Ð−11.1329°)) × sinh (0.3417Ð78.8671°) =

7.940x10−4 Ð90.4255°

The line constant D is:

D = A = 0.9464 + j0.0217 = 0.9466 Ð1.3150°

30

Therefore, the sending end line to neutral voltage, 𝑉𝑠 and the sending end current 𝐼𝑠 can

be computed by using the below matrix equation:

[𝑉𝑠𝐼𝑠

] = [𝐴 𝐵𝐶 𝐷

] x [𝑉𝑅

𝐼𝑅]

The polar form of the matrix equation is:

[𝑉𝑠𝐼𝑠

] = [0.9466 Ð1.3150° 141.8311 Ð68.1597°

7.940x10−4 Ð90.4255° 0.9466 Ð1.3150°] x [

𝑉𝑅

𝐼𝑅]

The line to neutral sending end voltage, 𝑉𝑆(𝐿−𝑁) can be computed by using the A,B line

constants, the line to neutral receiving end voltage, 𝑉𝑅(𝐿−𝑁) and the receiving end

current, 𝐼𝑅:

𝑉𝑆(𝐿−𝑁) =𝐴𝑉𝑅(𝐿−𝑁)

+ 𝐵𝐼𝑅

𝑉𝑆(𝐿−𝑁)= (0.9466 Ð1.3150°) x (199,186Ð0°) + (141.8311 Ð68.1597°) x

(92.9711Ð − 25.84°)

𝑉𝑆𝐿−𝑁= 198.69 Ð3.8105°𝑘𝑉

The sending end line-to-line voltage:

𝑉𝑆𝐿−𝐿 = (√3)x(198.69 Ð3.8105°𝑘𝑉)

𝑉𝑆𝐿−𝐿 = 344.15 Ð33.8105°𝑘𝑉

The sending end current 𝐼𝑆 can be calculated by using the C D line constants, the line to

neutral receiving end voltage, and the receiving end current:

𝐼𝑆 = 𝐶𝑉𝑅(𝐿−𝑁) + 𝐷𝐼𝑅

31

𝐼𝑆= (7.940x10−4 Ð90.4255°) x (199,186Ð0°)+(0.9466 Ð1.3150° ) x (92.9711Ð −

25.84°)

𝐼𝑆= 144.9657Ð57.0288°𝐴𝑚𝑝𝑠

The sending end power factor is:

𝜃𝑆 = 3.8105-57.0288= -53.2183

cos (𝜃𝑆) = 0.5988

The sending end power is:

𝑃𝑆 = (√3)𝑉𝑆(𝐿−𝐿)𝐼𝑆(𝑐𝑜𝑠𝜃𝑆)

𝑃𝑆= (√3)x(344.15 )x(144.9657)x(0.5528)

𝑃𝑆= 51.741 MW

The receiving end power is:

𝑃𝑅 = (√3)𝑉𝑅(𝐿−𝐿)𝐼𝑅(𝑐𝑜𝑠𝜃𝑅)

𝑃𝑅= (√3)x(345000)x(92.9711)x(0.9)

𝑃𝑅= 50 MW

The Power Loss, 𝑃𝐿𝑂𝑆𝑆 in the line can be computed by using the sending end power, 𝑃𝑆

and the receiving end power 𝑃𝑅:

𝑃𝐿𝑂𝑆𝑆 = 𝑃𝑆 − 𝑃𝑅

𝑃𝐿𝑂𝑆𝑆= 51.741 – 50 MW

𝑃𝐿𝑂𝑆𝑆= 1.74 MW

The percentage of voltage regulation can be computed by using the sending end line to

neutral voltage 𝑉𝑆(𝐿−𝑁), and the receiving end line to neutral voltage, 𝑉𝑅(𝐿−𝑁):

32

% VReg = 𝑉𝑆(𝐿−𝑁)−𝑉𝑅(𝐿−𝑁)

𝑉𝑅(𝐿−𝑁) x 100%

= 198.69−199.186

199.186 x 100%

% VReg =0.2490 %

This percentage (0.2490 %) of voltage regulation is within 5% of the required voltage

regulation. Therefore, the chosen ACSR conductor is a good choice for our design.

The transmission line efficiency is:

h = 𝑃𝑅

𝑃𝑆 x 100%

h= 50

51.741 x 100%

h= 96.63%

The new transmission line efficiency is 96.63 %, which is above the required efficiency

of 95%.

The sending end charge current at no-load is expressed as follows:

𝐼𝐶 = (1

2)(y 𝑙) 𝑉𝑆(𝐿−𝑁)

= (1

2)(5.518 x 10−6 Ð90°) (160) (198.69 Ð3.8105°)

= 80.3211Ð93.8105° Amp

The receiving end voltage rise at no load is:

𝑉𝑅(𝐿−𝑁)𝑛𝑜 𝑙𝑜𝑎𝑑 = 𝑉𝑆(𝐿−𝑁) − 𝐼𝐶(z ℓ)

33

= (198.69 Ð3.8105°) − (80.3211Ð93.8105°)*(0.7755 Ð81.63°)*(160)

= 209,480Ð2.6082° V

The line-to-line voltage rise at receiving end is:

𝑉𝑅(𝐿−𝐿)𝑛𝑜 𝑙𝑜𝑎𝑑 = (√3)𝑉𝑅(𝐿−𝑁)𝑛𝑜 𝑙𝑜𝑎𝑑

= 356,310 Ð2.6083+30° V

= 362,820 Ð32.6083° V

3.6 Corona Loss

We will use the below equation to see if the corona loss for our 345kV conductor will

exceed the limit of 0.6kW/km.

1

22 5

0

241( 25) ( ) 10C

rP f V V

D

kW

km

CP is corona power loss. is density correction factor. The conductor radius r =

0.0403ft and the spacing D = 22.394 ft. The transmission line is assumed located at

elevation of approximately 1000 ft. so normal atmospheric pressure is assumed to be

760 mmHg [torr.] and the temperate to be 25°C. With the frequency of 60Hz, the

receiving voltage is:

34

𝑉𝑅 =345𝑘𝑉

√3= 199,186 V

= 3.9211×𝑝

273+𝑡 =

3.9211×75

273+25= 0.986854

In fair weather the 𝐸0 of air is 21.1kV/cm

To determine for 𝑉0, we use the following equation:

𝑉0 = 𝐸0 * r *ln(D

r)

𝑉0 = 21.1*(0.48in × (2.54

1 in) * ln (

22.394𝑓𝑡

0.0403𝑓𝑡) = 163.807 kV

Now we have all the values to solve for the Corona loss,

𝑃𝐶 = (241

0.986854) ×(60 + 25) × (

0.0403

22.394)

1

2× (199.185-163.807)2 × 10−5 𝑘𝑊

𝑘𝑚 .

𝑃𝐶 = 0.031153 𝑘𝑊

𝑘𝑚 per phase.

The Corona loss is 0.031153 kW/km, which is within the required limit of 0.6kW/km for

the transmission line. The total corona loss is,

0.031153×257.49 = 8.02158 kW/phase

If the corona loss is not within the required limit then we will choose a different

conductor until the required limit of the corona loss is met.

35

Chapter 4

TRANSMISSION LINE DESIGN

4.1 Design Criteria

Before any size of cross-county transmission line can be designed, it is critical to

formulate and issue design criteria in a form of manual or check list, which is reviewed

and approved by critical decision makers on such projects. Although each project may

vary in complexity or geographical or climatic conditions, certain key components of

design criteria are standard in power engineering industry.

This report list the following most critical design criteria for cross-county overhead

transmission line [5] [6]:

Project Data:

Project name, identification of ownership, location of the project, terminal points, line

voltage, etc.

Site Data:

Geographic area, climatic conditions, seismic conditions, icing conditions, unusual

climatology (tornados, hurricanes, sand storms, extreme ice, and microburst), pollution

levels, etc.

Codes and Standards [4]:

The design of a cross-country overhead transmission line entails conformance to various

regulatory codes, regulations, and power industry standards, which include the

following:

36

GO-95 General Order 95-California Public Utility Commission

NESC National Electrical Safety Code

RUS Rural Utilities Service – Bulletin 1724E-200

ASCE American Society of Civil Engineers – Manual 74[B3]

EPA Environmental Protection Agency

OSHA Occupational Safety and Health Administration

FAA Federal Aviation Administration

NERC North American Electric Reliability Corporation

Design Details:

(a) Type of structures – Wood, steel poles, lattice, etc.

(b) Wire size and composition - ACSR, AWG, etc.

(c) Insulation types and configuration

(d) Shielding and grounding

(e) Corona and field effects

4.2 Route Selection:

Before a cross-country transmission line can be planned and designed, it is necessary to

study the map first, then survey the route and perform line staking. It is common to

study several alternate routes to ensure that the optimum path is selected for the design

permitting and construction process. These alternate routes will also be required for

environmental impact study and report (EIR) or the Siting Permit. It is also necessary

37

to consider biological constrains and potential electromagnetic frequency (EMF) effects

of the high-voltage overhead power lines in rural and urban areas.

Once the optimum route is selected, the preliminary design can commence with the use

of aerial photographs, satellite imagery, USGS maps or LIDAR data, which is primarily

used with the computer-based program, such as PLS-CADD [7]. The LIDAR data is a

commercially available database, which provides detailed topographical data in addition

to satellite imagery.

4.3 Reconnaissance and Preliminary Survey

Before or during the design stage of the transmission line project, it is common to

perform physical staking of the line using the maps and images developed during the

route selection process to make any adjustments or enhancements of the line or location

of the poles or structures, also known as the Point of Inflection (PI).

4.4 Drawings

Upon completion of the route survey, it is customary to produce the plan and profile

drawings which will show the elevation of the overhead line along the entire route with

all the critical data such spans between structures, sag and tension in the line, different

type of crossings, such as railroad tracks, highways and rivers, as well as conductor

clearance at every point in the line. These drawings will be required for a number of

different purposes, such as environmental assessment, regulatory review and approval of

the projects, developing the cost estimate and funding the projects.

38

In addition to the drawings, the engineers need to prepare and issue specifications for

material and construction work, both of which are issued for bidding purposes and

selection of vendors and contractors for the implementation of the projects.

This report presents the use of the PLS-CADD (Power Line Systems - Computer

Aided Design and Drafting) program for the design of the 345 kV transmission line.

PLS-CADD is a powerful overhead power line design program, which runs under

Microsoft Windows and contains graphical user interface, such as LIDAR for routing

the lines, selecting the structures, locating the structures. PLS-CADD also can produce

plan and profile drawings, sag and tension tables, 3-dimentional view of the line and

complete bill of material for each structures and pricing purposes.

Appendix A Presents partial Plan & Profile report to present the information generated

by PLS-CADD for the subject project and Appendices B through F present the results

of Sag & Tension analyses, line load analyses and other PLS-CADD reports. These

exhibits demonstrate the capability of the computer-based program in design available

for engineering and design of cross-country transmission lines.

39

4.5 Permits

One of the critical steps in developing cross-country transmission lines is securing

permits from various regulatory agencies and local justification. This step requires

significant amount of technical and environmental analysis to secure global or site

specific permits and authorizations. Hence, the preparation of the required permit

application requires a definitive design accompanied by all the pertinent data required

by respective permitting agencies, which could take a substantial amount of time and

coordination.

40

Chapter 5

CONSTRUCTION METHODS

5.1 Equipment and Material

The major equipment and materials used for constructing the cross-county

transmission lines are typically identified and specified using Plan & Profile

drawings, which could be developed using the computer, based program such as

PLS-CADD. This effort culminates in compiling bills of material, which often is

coded with industry standard part numbers or company specific material codes that

could be used in quoting and purchasing all the major equipment and material.

The critical items for overhead transmission lines are structures and conductors. The

structures can be mono-poles, also known as tubular steel poles (TSPs), lattice steel

structures, wood poles and H-Frames. The size and type of support structures are often

based on span lengths, loading stresses, environment and cost.

5.2 Special Construction Equipment

Basic tools needed to construct overhead transmission lines are as follows:

Conductor blocks

(a) Overhead ground wire blocks

(b) Catch-off blocks

(c) Sagging blocks

(d) Pulling lines

(e) Pulling grips

41

(f) Catch-off grips

(g) Swivels

(h) Running boards

(i) Conductor lifting hooks

(j) Hold-down blocks

5.3 Conductor Blocks

Conductor blocks are made in the following configurations:

(a) Single conductor

(b) Multiple-conductor

(c) Multiverse type (can be converted from bundle to single, and vice versa)

(d) Helicopter

5.4 Conductor Installation

The type and size of overhead conductor shall be in accordance with the design

drawings and specifications. The installation (pulling) of the conductors in rugged and

inaccessible locations will start with pulling a pilot line with a helicopter followed by

conventional wire puling methods. In the rugged terrain, the pilot line is sometimes

carried manually or by off-road vehicles.

5.5 Construction Techniques

Construction of a transmission line entails well-coordinated activities of various trades

and crafts-men, including linemen, equipment operators, laborers, contract supervisors

42

and equipment representatives. This stage of construction is preceded by procurement

of all the required equipment and material, receipt and storage of the items in time and

in quantities required to maintain the established work schedule and efficient workflow.

Due to the nature of the cross-country overhead transmission line project, it is critical to

maintain proper logistics, such as access road building, supply of equipment and

material and distribution of resources along the line route, all conducted safely and

efficiently. The impact of weather is also major element that controls the line

installation and needs to be incorporated into the work planning and schedules.

There are a number of established methods for each stage of line construction, including

vegetation clearing, grading, poles or structure erection, stringing and pulling

conductors. This report will not address each of these methods, but the best sources for

such information can be found in 1724-2011 EEE Guide for Preparation of a

Transmission Lines Design Criteria Document, 2011. [5]

Selected photographs below are provided for general information about transmission

line construction in various terrain (Courtesy of WestPower, Incorporated [9])

43

Figure 5.1 Transmission Line Construction – River Crossing

Figure 5.2 Transmission Line Construction in Rugged Terrain

Figure 5.3 Transmission Line Construction Aerial

44

Figure 5.4 Transmission Line Mode of Construction by Air

Figure 5.5 Transmission Line Construction Overhead Model of a Tower

45

Chapter 6

INFRASTRUCTURE REGULATION AND SECURITY TRENDS

The electrical infrastructure in the United States and other countries is undergoing major

changes with steadily increasing demand for energy and introduction of renewable

power generating resources. These trends are affecting the planning, development and

operation of power grid and associated infrastructure.

On the planning side, the builders and operators of cross country transmission lines are

increasingly affected by federal, regional and local regulatory policies which apply to

siting, permitting and security of new or existing transmission lines. On the technical

side, the electrical grid - the transmission and distribution system - is undergoing

significant modernization with advanced technologies, such as smart-grid and real-time

information collection systems. On the security side of the current trend, the electric

infrastructure and transmission lines specifically have been gradually reinforced

physically and via cyber security measures. These major trends are discussed in

“Regulatory Trends [7] [8] below.

Regulatory Trends [7] [8]

The electrical infrastructure, which includes transmission lines, substations and power

generation plants are regulated or monitored by two key federal government agencies in

the United States. The Federal Energy Regulatory Commission (FERC) collects

transmission information from investor owned utilities and intrastate bulk lines. The

Energy Information Administration (EIA) collects similar information from entities

46

outside of FERC jurisdiction - Independent Power Producers (IPPs), cooperatives,

municipal systems, Federal power and Texas. EIA also collects data from generators

under FERC jurisdiction. The Department of Energy collects trade data with Canada

and Mexico. The Department of Agriculture collects data from cooperatives having

loans with the Rural Utilities Service. [1]

The operation of transmission lines is regulated by the North American Electric

reliability Council (NERC), which operates under oversight of FERC. In addition to

federal regulatory agencies, the transmission line siting and permitting is regulated by

numerous other state and local agencies in California, including California Independent

System Operator (CA-ISO) and California Public Utility Commission (CPUC).

The overall structures of the government agencies that oversee the transmission lines is

shown on figure below and described in numerous government publications and

professional articles, some of which are listed in the references of this report.

47

ERCOT Electric Reliability Council of Texas

FRCC: Florida Reliability Coordinating Council

MRO: Midwest Reliability Organization

NPCC: Northwest Power Coordinating Council

RFC: Reliability First Corporation

SERC: Southeastern Electric Reliability Council

SPP: Southwest Power Pool Inc.

WECC: Western Electricity Coordinating Council

48

Chapter 7

CONCLUSIONS

In an electric power system, transmission lines carry electric energy from one point to

another. There are many factors that need to be considered in the process of building a

transmission line as outlined in Chapter 2 and Chapter 3.

For our project, we designed a long transmission line. We used a voltage level of 345

kV, a total power of 200 MW, a lagging power factor of 0.95, and we also chose an

appropriate ACSR conductor at the voltage regulation also needed to be within 5%, with

an efficiency of 95% or more. After performing the calculations to decide which ACSR

conductor is best fit for our transmission line design, we choose the ACSR conductor

that was 397.5 kcmil.

Chapter 2 gave an outline for our transmission line design, Chapter 3 outlined the

mathematical equations used for analysis, and Chapter 4 provides the design basis of for

the transmission line studies in the report.

The study of the subject transmission line was based on several computer-based

programs widely used in power engineering industry, including the following:

PLS-CADD (www.powline.com) - Transmission Line Design Program

(The output of this program is presented in Appendices A, B, C, D, E & F)

ASPEN (www.aspeninc.com) - Power System Analysis Program

http://www.powline.com/

http://www.aspeninc.com/

49

(The output of this program is presented in Appendix G)

MATLAB (www.mathworks.com) – Technical Computing language Software

(The output of this program is presented in Appendix H)

http://www.mathworks.com)/

50

APPENDIX A. Plan & Profile Report (Partial)

55

APPENDIX B. PLS-CADD Load Cases Report PLS-CADD Version 12.30x64

Project Name: 'c:westpower\alex 345\alex345-5.DON'

Criteria Notes:

Typical 2012 NESC C2-2007 Criteria File for PLS-CADD Created December 31, 2006 Version 8.10

Assumed NESC Heavy Combined Ice and Wind Loading District (Rule 250B)

Assumed 90 MPH Extreme Wind Loading (Rule 250C)

Assumed 1" Extreme Ice with 30 MPH Concurrent Wind Loading (Rule 250D)

Assumed Maximum Operating Temperature of 212 F

Assumed 1" Extreme Ice (Non-NESC)

Assumed Grade B Construction

<<Illustration of NESC provisions include>> > Combined Ice and Wind District Loading NESC Heavy per Rule 250B, Page 177

> Extreme Wind Loading per Rule 250C, Page 177, Coefficients and Gust Response Factors per Equations in Tables

250-2 and 250-3

> 90 MPH Basic Wind Speed, 3 second Gust Wind Speed, Figure 250-2 Beginning on Page 180

> Grade B Construction "Method A" per Table 253-1, Page 197 and Table 261-1A, Page 207

> Extreme Ice with Concurrent Wind Loading per Rule 250D, Page 179

> 1" Basic Ice Diameter with Concurrent 30 MPH Basic Wind Speed, Figure 250-3 Beginning on Page 184

> Cable Tension and Automatic Sagging Limits per Rule 261H1, Page 204

**** PLEASE NOTE - Many experts consider these limits to be high and could lead to severe aeolian vibration

**** PLS recommends checking with your cable manufacturer and/or other standards for recommended values

> Insulator Mechanical Strengths per Rule 277 - Important Note for Strength Check:

**** NESC Rule 277 specifically excludes Rule 253 Load Factors for checking the mechanical strength of insulators

**** This Criteria checks Insulators for ALL cases using a Strength Factor of 1.0 applied to insulator working load

roperties.

**** When specifying the insulator strength properties in Components/Insulators in TOWER and PLS-POLE,

the manufacturer`s recommended load capacities shall be used per NESC Table 277-1. This is normally the RTL and RCL

values published by the non-ceramic insulator manufacturers. See IEEE Std 1572™-2004 IEEE Guide for Application of

Composite Line Post Insulators for further clarification.

**** Per Rule 277, the responsible engineer should decide what "proper allowance" is for Rules 250C and 250D and

modify load cases accordingly

**** User may prefer to add other specific load cases utilizing alternative Strength Factors ****

**** Coordination of Load Factors, Strength Factors, and Component strength properties is the responsibility of the

RESPONSIBLE ENGINEER

**** See Tech Note at http://www.powline.com/products/nesc_insulators.html for additional discussion ****

> Structure Loads criteria includes typical Full Structure DE cases

POWER LINE SYSTEMS, INC. IS NOT RESPONSIBLE FOR THE ACCURACY OF THE CONTENT HEREIN OR RESULTS OBTAINED FROM ITS USE

ON ANY PROJECT.

THIS FILE IS PROVIDED FOR ILLUSTRATION ONLY. CRITERIA SHOULD BE CHECKED AND MODIFIED AS NECESSARY BY A RESPONSIBLE

ENGINEER.

FAMILIAR WITH THE NESC AND LOCAL REQUIREMENTS OF THE AREA IN WHICH THE PROJECT IS LOCATED, AND ITS APPLICATION.

RESPONSIBLE ENGINEER SHOULD VERIFY EXTREME WIND, CONCURRENT ICE AND WIND, AND EXTREME ICE PARAMETERS FOR THEIR

APPLICABLE REGION.

RESPONSIBLE ENGINEER SHOULD VERIFY MAXIMUM OPERATING CONDITION FOR THEIR APPLICABLE PROJECT

RESPONSIBLE ENGINEER SHOULD VERIFY CONDITIONS AND FACTORS USED FOR INSULATOR STRENGTH CHECKS

RESPONSIBLE ENGINEER SHOULD ADD ANY ADDITIONAL CRITERIA THAT MAY BE REQUIRED BEYOND THE NESC

RESPONSIBLE ENGINEER SHOULD REMOVE THIS DISCLAIMER AND MODIFY NOTES ABOVE AS APPLICABLE WHEN ASSUMING CHARGE OF THIS

CRITERIA

Criteria Report

Weather Cases

WC Description Air Wind Wind Wire Wire Wire Wire Ambient Weather NESC Wire

Wind Wire

# Density Vel. Pres. Ice Ice Ice Temp Temp Load Constant

Height Gust

Factor Thick Density Load Factor

Adjust Response

(psf/mph^2) (mph) (psf) (in) (lbs/ft^3) (lbs/ft) (deg F) (deg F) (lbs/ft)

Model Factor

--------------------------------------------------------------------------------------------------------------------------------

1 NESC Light 0.00256 59 9.0 0.00 0.000 0.00 30 30 1.00 0.30

None 1

2 GO 95 Light 0.00256 56 8.0 0.00 0.000 0.00 25 25 1.00 0.00

None 1

3 NESC Extreme Wind (250C) 0.00256 85 18.5 0.00 0.000 0.00 60 60 1.00 0.00 NESC

2007 NESC 2007

4 IID Extreme Wind 0.00256 100 25.6 0.00 0.000 0.00 60 60 1.00 0.00 NESC

2007 NESC 2007

5 Uplift 0.00256 0 0.0 0.00 0.000 0.00 -10 -10 1.00 0.00

None 1

6 No Wind (SWING 1) 0.00256 0 0.0 0.00 0.000 0.00 60 60 1.00 0.00

None 1

7 NESC Blowout 6PSF 0.00256 48 6.0 0.00 0.000 0.00 60 60 1.00 0.00

None 1

8 High Wind (SWING 3) 0.00256 90 20.7 0.00 0.000 0.00 60 60 1.00 0.00

None 1

9 Vibration Control 0.00256 0 0.0 0.00 0.000 0.00 60 60 1.00 0.00

None 1

56

10 Mean Annual Temperature 0.00256 40 4.0 0.00 0.000 0.00 70 70 1.00 0.00

None 1

11 NESC Deflection 0.00256 0 0.0 0.00 0.000 0.00 90 90 1.00 0.00

None 1

12 0 Deg F 0.00256 0 0.0 0.00 0.000 0.00 0 0 1.00 0.00

None 1

13 25 Deg F 0.00256 0 0.0 0.00 0.000 0.00 25 25 1.00 0.00

None 1

14 60 Deg F 0.00256 0 0.0 0.00 0.000 0.00 60 60 1.00 0.00

None 1

15 100 Deg F 0.00256 0 0.0 0.00 0.000 0.00 100 100 1.00 0.00

None 1

16 120 Deg F 0.00256 0 0.0 0.00 0.000 0.00 120 120 1.00 0.00

None 1

17 302 Deg F 0.00256 0 0.0 0.00 0.000 0.00 302 302 1.00 0.00

None 1

18 356 Deg F 0.00256 0 0.0 0.00 0.000 0.00 356 356 1.00 0.00

None 1

19 Maximum Operating 0.00256 0 0.0 0.00 0.000 0.00 302 302 1.00 0.00

None 1

Cable Tension Criteria

LC WC Description Cable Allowable Maximum Maximum Applicable

# # Condition %Ultimate Tension Catenary Cable

(lbs) (ft)

--------------------------------------------------------------------------------

1 1 NESC Light Initial RS 60.000 0.000 0.000 ALL CABLES

2 9 Vibration Control Creep RS 19.000 0.000 0.000 ALL CABLES

3 14 60 Deg F Initial RS 35.000 0.000 0.000 ALL CABLES

4 14 60 Deg F Creep RS 25.000 0.000 0.000 ALL CABLES

Automatic Sagging Criteria

LC WC Description Cable Allowable Maximum Maximum Applicable

# # Condition %Ultimate Tension Catenary Cable

(lbs) (ft)

--------------------------------------------------------------------------------

1 1 NESC Light Initial RS 60.000 0.000 0.000 ALL CABLES

2 9 Vibration Control Creep RS 19.000 0.000 0.000 ALL CABLES

3 14 60 Deg F Initial RS 35.000 0.000 0.000 ALL CABLES

4 14 60 Deg F Creep RS 25.000 0.000 0.000 ALL CABLES

Weight Span Criteria (Method 1)

Condition WC Weather Case Cable

# Description Condition

----------------------------------------------------------------------

Condition 1 (usually Wind) 3 NESC Extreme Wind (250C) Initial RS

Condition 2 (usually Cold) 5 Uplift Initial RS

Condition 3 (usually Ice) 1 NESC Light Initial RS

Interaction Diagram Criteria

LC WC Weather Case Cable

# # Description Condition

--------------------------------------------

1 1 NESC Light Initial RS




5 3 NESC Extreme Wind (250C) Initial RS




9 5 Uplift Initial RS









Structure Groups Criteria

Group Group Rule for

Load Cases Structures

Name Description Group Membership

In Group In Group

--------------------------------------------------------------------------------------------------------------------------------

All Built in group that all structures belong to Automatic: all structures

34 1065

Has DE At least one dead end set on structure Automatic: has a DE between sets 1 and 60

8 1065

No DE No dead end sets on structure Automatic: has no DE between sets 1 and 60

0 0

All sets DE All sets on structure are dead end Automatic: has only DE between sets 1 and

60 0 5

57

Not all sets DE At least one set on structure is not dead end Automatic: has non DE between sets 1 and 60

0 1060

Angle Structure near nonzero line angle Automatic: line angle outside 0.00 to 0.00

(deg) within 0.33 (ft) of structure 0 0

PLS-POLE PLS-POLE created structure Automatic: PLS-POLE created

0 1065

PLS-POLE has DE PLS-POLE created structure with at least one dead end set Automatic: PLS-POLE created and has a DE

between sets 1 and 60 0 1065

PLS-POLE no DE PLS-POLE created structure without any dead end sets Automatic: PLS-POLE created and has no DE


PLS-POLE angle PLS-POLE created structure near nonzero line angle Automatic: PLS-POLE created and line angle

outside 0.00 to 0.00 (deg) within 0.33 (ft) of structure 0 0

TOWER TOWER created structure Automatic: TOWER created

0 0

TOWER has DE TOWER created structure with at least one dead end set Automatic: TOWER created and has a DE


TOWER no DE TOWER created structure without any dead end sets Automatic: TOWER created and has no DE


TOWER angle TOWER created structure near nonzero line angle Automatic: TOWER created and line angle

outside 0.00 to 0.00 (deg) within 0.33 (ft) of structure 0 0

Structure Loads Criteria

LC WC Load Case Cable Wind Bisect Wire Wire + Wire Struct Struct Struct. Struct. Struct.

Pole Pole

# # Description Condition Dir. Wind Vert. Struct. Tension Weight Wind Wind Ice Ice

Tip Tip

Angle Load Wind Load Load Area Load Thick Density

Deflection Deflect

Factor Load Factor Factor Factor Model

Check Limit

Factor (in) (lbs/ft^3)

% or (ft)

--------------------------------------------------------------------------------------------------------------------------------

1 2 1-GO 95 Light NA Initial RS NA+ 1.50 1.50 1.50 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

2 2 1-GO 95 Light NA Initial RS NA- 1.50 1.50 1.50 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

3 1 1-NESC RULE 250B Initial RS NA+ 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

4 1 1-NESC RULE 250B Initial RS NA- 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

5 3 2-NESC RULE 250C Initial RS NA+ 1.00 1.00 1.00 1.00 1.00 NESC 2007 0.00 0.000

No Limit 0.00

6 3 2-NESC RULE 250C Initial RS NA- 1.00 1.00 1.00 1.00 1.00 NESC 2007 0.00 0.000

No Limit 0.00

7 4 7-IID Extreme Wi Initial RS NA+ 1.25 1.25 1.25 1.25 1.00 NESC 2007 0.00 0.000

No Limit 0.00

8 4 7-IID Extreme Wi Initial RS NA- 1.25 1.25 1.25 1.25 1.00 NESC 2007 0.00 0.000

No Limit 0.00

9 14 9-NESC (Construc Initial RS NA+ 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

10 11 9- NESC Deflecti Creep RS NA+ 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

11 9 9- Vibration Con Creep RS NA+ 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

12 1 Intact Unbalance Initial RS NA+ 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

13 1 Intact Unbalance Initial RS NA- 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

14 1 Broken Unbalance Initial RS NA+ 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

15 1 Broken Unbalance Initial RS NA- 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

16 1 Broken Unbalance Initial RS NA+ 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

17 1 Broken Unbalance Initial RS NA- 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

18 1 4-NESC Brk Condu Initial RS NA+ 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

19 1 4-NESC Brk Condu Initial RS NA- 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

20 1 4-NESC Brk Condu Initial RS NA+ 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

21 1 4-NESC Brk Condu Initial RS NA- 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

22 4 4-Ext Wind Brk C Initial RS NA+ 1.25 1.25 1.25 1.25 1.00 Wind on Face 0.00 0.000

No Limit 0.00

23 4 4-Ext Wind Brk C Initial RS NA- 1.25 1.25 1.25 1.25 1.00 Wind on Face 0.00 0.000

No Limit 0.00

24 4 4-Ext Wind Brk C Initial RS NA+ 1.25 1.25 1.25 1.25 1.00 Wind on Face 0.00 0.000

No Limit 0.00

25 4 4-Ext Wind Brk C Initial RS NA- 1.25 1.25 1.25 1.25 1.00 Wind on Face 0.00 0.000

No Limit 0.00

26 4 10-NESC Wind Onl Initial RS NA+ 1.00 1.00 1.00 1.00 1.00 NESC 2007 0.00 0.000

No Limit 0.00

27 4 10-NESC Wind Onl Initial RS NA- 1.00 1.00 1.00 1.00 1.00 NESC 2007 0.00 0.000

No Limit 0.00

28 1 NESC RULE 250B U Initial RS NA+ 1.00 2.50 1.65 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

29 1 NESC RULE 250B U Initial RS NA- 1.00 2.50 1.65 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

30 1 NESC RULE 277 In Initial RS NA+ 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

31 1 NESC RULE 277 In Initial RS NA- 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

58

32 5 Uplift Initial RS NA+ 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

33 1 Strain - Intact Initial RS NA+ 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

34 1 Strain - Intact Initial RS NA- 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

35 1 Strain - Broken Initial RS NA+ 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

36 1 Strain - Broken Initial RS NA- 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

37 1 Strain - Broken Initial RS NA+ 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

38 1 Strain - Broken Initial RS NA- 1.50 2.50 1.65 1.50 1.00 Wind on Face 0.00 0.000

No Limit 0.00

39 1 SW-Broken Unbala Initial RS NA+ 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

40 1 SW-Broken Unbala Initial RS NA- 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

41 1 SW-Broken Unbala Initial RS NA+ 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

42 1 SW-Broken Unbala Initial RS NA- 1.00 1.00 1.00 1.00 1.00 Wind on Face 0.00 0.000

No Limit 0.00

Strength Factors for each Load Case

LC WC Load Case Strength Strength Strength Strength Strength Strength Strength Strength Strength Strength

# # Description Factor Factor Factor Factor Factor Factor Factor Factor Factor Factor

Steel Poles Wood Concrete Concrete Concrete Guys Non- Braces Insul- Found-

Tubular Arms Poles Poles Poles Poles Tubular ators ation

Towers Ultimate First Zero Arms

Crack Tension

------------------------------------------------------------------------------------------------------------------

1 2 1-GO 95 Light NA 1.00 0.25 0.56 0.00 0.00 0.50 0.67 0.67 0.33 0.33

2 2 1-GO 95 Light NA 1.00 0.25 0.56 0.00 0.00 0.50 0.67 0.67 0.33 0.33

3 1 1-NESC RULE 250B 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

4 1 1-NESC RULE 250B 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

5 3 2-NESC RULE 250C 1.00 0.75 1.00 0.00 0.00 0.90 0.75 0.75 0.80 1.00

6 3 2-NESC RULE 250C 1.00 0.75 1.00 0.00 0.00 0.90 0.75 0.75 0.80 1.00

7 4 7-IID Extreme Wi 1.00 0.75 1.00 0.00 0.00 0.90 0.75 0.75 0.80 1.00

8 4 7-IID Extreme Wi 1.00 0.75 1.00 0.00 0.00 0.90 0.75 0.75 0.80 1.00

9 14 9-NESC (Construc 1.00 0.75 1.00 0.00 0.00 0.90 1.00 1.00 0.50 1.00

10 11 9- NESC Deflecti 1.00 0.75 1.00 0.00 0.00 0.90 1.00 1.00 0.50 1.00

11 9 9- Vibration Con 1.00 0.75 1.00 0.00 0.00 0.90 1.00 1.00 0.50 1.00

12 1 Intact Unbalance 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

13 1 Intact Unbalance 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

14 1 Broken Unbalance 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00




18 1 4-NESC Brk Condu 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

19 1 4-NESC Brk Condu 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

20 1 4-NESC Brk Condu 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

21 1 4-NESC Brk Condu 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

22 4 4-Ext Wind Brk C 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

23 4 4-Ext Wind Brk C 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

24 4 4-Ext Wind Brk C 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

25 4 4-Ext Wind Brk C 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

26 4 10-NESC Wind Onl 1.00 0.75 1.00 0.00 0.00 0.90 0.75 0.75 0.80 1.00

27 4 10-NESC Wind Onl 1.00 0.75 1.00 0.00 0.00 0.90 0.75 0.75 0.80 1.00

28 1 NESC RULE 250B U 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

29 1 NESC RULE 250B U 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

30 1 NESC RULE 277 In 1.00 0.75 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

31 1 NESC RULE 277 In 1.00 0.75 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

32 5 Uplift 1.00 0.75 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

33 1 Strain - Intact 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

34 1 Strain - Intact 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

35 1 Strain - Broken 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

36 1 Strain - Broken 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

37 1 Strain - Broken 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

38 1 Strain - Broken 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

39 1 SW-Broken Unbala 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

40 1 SW-Broken Unbala 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

41 1 SW-Broken Unbala 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

42 1 SW-Broken Unbala 1.00 0.65 1.00 0.00 0.00 0.90 0.65 0.65 0.50 1.00

Cable Load Adjustments for each Load Case

LC WC Load Case Struct | Command 1 Command 1 Command 1 | Command 2

Command 2 Command 2 | Command 3 Command 3 Command 3 |

# # Description Groups | Wire(s) Value | Wire(s)

Value | Wire(s) Value |

On Which | Set: (lbs) | Set:

(lbs) | Set: (lbs) |

To Apply | Phase: (deg) | Phase:

(deg) | Phase: (deg) |

| Side: (%) | Side:

(%) | Side: (%) |

1 2 1-GO 95 Light NA 'All' Back Spans Add Vert. Load (wire coord. system) 200.0

2 2 1-GO 95 Light NA 'All' Back Spans Add Vert. Load (wire coord. system) 200.0

3 1 1-NESC RULE 250B 'All' Back Spans Add Vert. Load (wire coord. system) 200.0

4 1 1-NESC RULE 250B 'All' Back Spans Add Vert. Load (wire coord. system) 200.0

5 3 2-NESC RULE 250C 'All' Back Spans Add Vert. Load (wire coord. system) 300.0

6 3 2-NESC RULE 250C 'All' Back Spans Add Vert. Load (wire coord. system) 300.0

7 4 7-IID Extreme Wi 'All' Back Spans Add Vert. Load (wire coord. system) 240.0

8 4 7-IID Extreme Wi 'All' Back Spans Add Vert. Load (wire coord. system) 240.0

59

9 14 9-NESC (Construc 'All' Back Spans Add Vert. Load (wire coord. system) 300.0

10 11 9- NESC Deflecti 'All'

11 9 9- Vibration Con 'All'

12 1 Intact Unbalance 'All' Back Spans Add Vert. Load (wire coord. system) 300.0

13 1 Intact Unbalance 'All' Back Spans Add Vert. Load (wire coord. system) 300.0

14 1 Broken Unbalance 'All' 5:1:Ahead # Broken Subconductors 1.0 5:1:Back %

Hor. Ten. (changes V, T and L) 65.0 Back Spans Add Vert. Load (wire coord. system) 300.0


Hor. Ten. (changes V, T and L) 65.0 Back Spans Add Vert. Load (wire coord. system) 300.0


Hor. Ten. (changes V, T and L) 65.0 Ahead Spans Add Vert. Load (wire coord. system) 300.0


Hor. Ten. (changes V, T and L) 65.0 Ahead Spans Add Vert. Load (wire coord. system) 300.0

18 1 4-NESC Brk Condu 'Has DE' Back Spans # Broken Subconductors 100.0 Ahead Spans Add

Vert. Load (wire coord. system) 200.0

19 1 4-NESC Brk Condu 'Has DE' Back Spans # Broken Subconductors 100.0 Ahead Spans Add


20 1 4-NESC Brk Condu 'Has DE' Ahead Spans # Broken Subconductors 100.0 Back Spans Add


21 1 4-NESC Brk Condu 'Has DE' Ahead Spans # Broken Subconductors 100.0 Back Spans Add


22 4 4-Ext Wind Brk C 'Has DE' Back Spans # Broken Subconductors 100.0 Ahead Spans Add


23 4 4-Ext Wind Brk C 'Has DE' Back Spans # Broken Subconductors 100.0 Ahead Spans Add


24 4 4-Ext Wind Brk C 'Has DE' Ahead Spans # Broken Subconductors 100.0 Back Spans Add


25 4 4-Ext Wind Brk C 'Has DE' Ahead Spans # Broken Subconductors 100.0 Back Spans Add


26 4 10-NESC Wind Onl 'All'

27 4 10-NESC Wind Onl 'All'

28 1 NESC RULE 250B U 'All'

29 1 NESC RULE 250B U 'All'

30 1 NESC RULE 277 In 'All'

31 1 NESC RULE 277 In 'All'

32 5 Uplift 'All'

33 1 Strain - Intact 'All' Back Spans Add Vert. Load (wire coord. system) 200.0

34 1 Strain - Intact 'All' Back Spans Add Vert. Load (wire coord. system) 200.0

35 1 Strain - Broken 'All' Ahead Spans # Broken Subconductors 1.0 Back Spans Add


36 1 Strain - Broken 'All' Ahead Spans # Broken Subconductors 1.0 Back Spans Add


37 1 Strain - Broken 'All' Back Spans # Broken Subconductors 1.0 Ahead Spans Add


38 1 Strain - Broken 'All' Back Spans # Broken Subconductors 1.0 Ahead Spans Add


39 1 SW-Broken Unbala 'All' 1:1:Ahead # Broken Subconductors 1.0 Back Spans Add


40 1 SW-Broken Unbala 'All' 1:1:Ahead # Broken Subconductors 1.0 Back Spans Add


41 1 SW-Broken Unbala 'All' 1:1:Back # Broken Subconductors 1.0 Ahead Spans Add


42 1 SW-Broken Unbala 'All' 1:1:Back # Broken Subconductors 1.0 Ahead Spans Add


Survey Point Clearance Criteria



-------------------------------------

1 1 NESC Light Max Sag RS

2 19 Maximum Operating Max Sag RS


4 7 NESC Blowout 6PSF Max Sag RS

Danger Tree Locator Criteria



-------------------------------------





Survey Point Clearance and Danger Tree Locator functions ARE NOT considering a Continuous Range

of wind values from left blowout to right blowout.

Survey Point Clearance functions are treating points with insufficient vertical clearance but

adequate horizontal clearance as questionable violations and flagging them with blue markers

in graphics views and a blue "??" in reports.

Phase Clearance Criteria



-------------------------------------

1 19 Maximum Operating Creep RS

2 19 Maximum Operating Creep RS

Insulator Swing Criteria

60

Condition WC Weather Case Cable

# Description Condition

------------------------------------------------

Condition 1 6 No Wind (SWING 1) Creep RS

Condition 2 7 NESC Blowout 6PSF Creep RS

Condition 3 8 High Wind (SWING 3) Creep RS

Blowout and Departure Angle Report Criteria



--------------------------------------------


2 3 NESC Extreme Wind (250C) Max Sag RS




6 14 60 Deg F Creep RS

Galloping Criteria

Weather case for swing angle: 10 Mean Annual Temperature C

Weather case for sag: : 10 Mean Annual Temperature C

Galloping amplitude safety factor (multiplies major axis for all methods): 1.00

Checking single loop (Davison)

Checking double loop (Toye)

Note that any given galloping ellipse is only checked against other ellipses that

share the same start and stop structures (these will be marked as N/A below).

Weight spans calculated by exact method using catenary in blown out plane

Wind & Weight Span Report



------------------------------------


2 4 IID Extreme Wind Initial RS



Weather case for final after creep '60 Deg F'

Weather case for final after load NESC Light

Clearance line voltage (kV) 345, clearance line vertical buffer (ft) 2

Display of centerline and side profile clearance lines turned ON.

Display of spikes for points requiring additional clearance turned ON.

Spikes are drawn for all feature codes (no codes have been exCLuded)

Wire Clearance Line

Wire Wire Clearance Views Voltage Weather Cable Vertical Horizontal

Clearance Clearance Line in which (kV) Case Condition Shift Shift

Line Line Type to display Down Right

# Label (ft) (ft)

------------------------------------------------------------------------------------------------------------------------------

1 345 Profile below wire Prof, Sheet prof 345 Maximum Operating Creep RS 0 0

Maximum tensions calculated using actual section geometry

Terrain:

Ground profile width (ft) 10

Display width (ft) 50

Code specific wind and terrain parameters

NESC constant is not multiplied by the number of independent wires specified in the cable file (not NESC 2012 compliant).

Bimetallic conductor settings:

Default settings from CRI file (used for wires that do not have conductor specific settings):

Outer strands do not take compression at high temperature.

SAPS Finite Element Sag-Tension:

SAPS Analysis Level 2

Option to include chained insulators in L2 and L3 models (always included in L4) is turned OFF

Default attachment stiffnesses (for level 2 analysis provided, may be overridden with attachment point specific value in

Section/Modify)

Dead Ends: 0 (lbs/ft) Transverse, 0 (lbs/ft) Longitudinal

Non dead end with post insulator: 0 (lbs/ft) Transverse, 0 (lbs/ft) Longitudinal

Non dead end with non post insulator: 0 (lbs/ft) Transverse, 0 (lbs/ft) Longitudin

61

APPENDIX C. H-Frame Structure Design

62

APPENDIX D. Sag & Tension Report-Conductors

Project Name: 'c\AlexT 345\alex345-5.DON'

Criteria Notes:

Typical 2012 NESC C2-2007 Criteria File for PLS-CADD Created December 31, 2006 Version 8.10

Assumed NESC Heavy Combined Ice and Wind Loading District (Rule 250B)



Assumed Maximum Operating Temperature of 212 F

Assumed 1" Extreme Ice (Non-NESC)

Assumed Grade B Construction

> Combined Ice and Wind District Loading NESC Heavy per Rule 250B, Page 177

> Extreme Wind Loading per Rule 250C, Page 177, Coefficients and Gust Response Factors per Equations in Tables

250-2 and 250-3

> 90 MPH Basic Wind Speed, 3 second Gust Wind Speed, Figure 250-2 Beginning on Page 180

> Grade B Construction "Method A" per Table 253-1, Page 197 and Table 261-1A, Page 207

> Extreme Ice with Concurrent Wind Loading per Rule 250D, Page 179

> 1" Basic Ice Diameter with Concurrent 30 MPH Basic Wind Speed, Figure 250-3 Beginning on Page 184

> Cable Tension and Automatic Sagging Limits per Rule 261H1, Page 204

<<Illustration of NESC provisions include>>

**** PLEASE NOTE - Many experts consider these limits to be high and could lead to severe aeolian vibration.

**** PLS recommends checking with your cable manufacturer and/or other standards for recommended values.

> Insulator Mechanical Strengths per Rule 277 - Important Note for Strength Check:

**** NESC Rule 277 specifically excludes Rule 253 Load Factors for checking the mechanical strength of insulators

**** This Criteria checks Insulators for ALL cases using a Strength Factor of 1.0 applied to insulator working load

properties.

**** When specifying the insulator strength properties in Components/Insulators in TOWER and PLS-POLE,

the manufacturer`s recommended load capacities shall be used per NESC Table 277-1. This is normally the RTL and RCL

values published by the non-ceramic insulator manufacturers. See IEEE Std 1572™-2004 IEEE Guide for Application of

Composite Line Post Insulators for further clarification.

**** Per Rule 277, the responsible engineer should decide what "proper allowance" is for Rules 250C and 250D and

modify load cases accordingly

**** User may prefer to add other specific load cases utilizing alternative Strength Factors.

**** Coordination of Load Factors, Strength Factors, and Component strength properties is the responsibility of the

RESPONSIBLE ENGINEER

**** See Tech Note at http://www.powline.com/products/nesc_insulators.html for additional discussion.

> Structure Loads criteria includes typical Full Structure DE cases

POWER LINE SYSTEMS, INC. IS NOT RESPONSIBLE FOR THE ACCURACY OF THE CONTENT HEREIN OR RESULTS OBTAINED FROM ITS USE

ON ANY PROJECT.

THIS FILE IS PROVIDED FOR ILLUSTRATION ONLY. CRITERIA SHOULD BE CHECKED AND MODIFIED AS NECESSARY BY A RESPONSIBLE

ENGINEER.

FAMILIAR WITH THE NESC AND LOCAL REQUIREMENTS OF THE AREA IN WHICH THE PROJECT IS LOCATED, AND ITS APPLICATION.

RESPONSIBLE ENGINEER SHOULD VERIFY EXTREME WIND, CONCURRENT ICE AND WIND, AND EXTREME ICE PARAMETERS FOR THEIR

APPLICABLE REGION.

RESPONSIBLE ENGINEER SHOULD VERIFY MAXIMUM OPERATING CONDITION FOR THEIR APPLICABLE PROJECT

RESPONSIBLE ENGINEER SHOULD VERIFY CONDITIONS AND FACTORS USED FOR INSULATOR STRENGTH CHECKS

RESPONSIBLE ENGINEER SHOULD ADD ANY ADDITIONAL CRITERIA THAT MAY BE REQUIRED BEYOND THE NESC

RESPONSIBLE ENGINEER SHOULD REMOVE THIS DISCLAIMER AND MODIFY NOTES ABOVE AS APPLICABLE WHEN ASSUMING CHARGE OF THIS

CRITERIA

Section #12 from structure #539 to structure #1065, start set #33 'CONDUCTOR_BCK', end set #3 ''

Cable 'c:\3-10-12\old d\cables\acsr\ibis_acsr.wir', Ruling span (ft) 823.461

Sagging data: Catenary (ft) 5909.62, Horiz. Tension (lbs) 3230.2 Condition I Temperature (deg F) 60

Weather case for final after creep 60 Deg F, Equivalent to 41.0 (deg F) temperature increase

Weather case for final after load NESC Light, Equivalent to 19.9 (deg F) temperature increase

Ruling Span Sag Tension Report

--------Weather Case------- | --Cable Load-- | ----R.S. Initial Cond.---- | -----R.S. Final Cond.----- | -----R.S.

Final Cond.----- |

| | | --------After Creep------- | --------

After Load-------- |

# Description | Hor. Vert Res. | Max. Hori. Max R.S. | Max. Hori. Max R.S. | Max. Hori.

Max R.S. |

| -----Load----- |Tens. Tens. Ten C Sag |Tens. Tens. Ten C Sag |Tens. Tens.

Ten C Sag |

| ---(lbs/ft)--- |(lbs) (lbs) %UL (ft) (ft) |(lbs) (lbs) %UL (ft) (ft) |(lbs) (lbs)

%UL (ft) (ft) |

----------------------------------------------------------------------------------------------------------------------

-

1 NESC Light 0.59 0.55 1.10 5721 5284 35 4794 17.69 5419 4992 33 4529 18.73 5721 5284

35 4794 17.69

2 GO 95 Light 0.52 0.55 0.76 4722 4361 29 5770 14.70 4262 3920 26 5186 16.35 4578 4222

28 5586 15.18

3 NESC Extreme Wind (250C) 0.96 0.55 1.10 5227 4954 32 4494 18.88 4900 4632 30 4202 20.19 5151 4879

32 4426 19.16

4 IID Extreme Wind 1.33 0.55 1.43 6070 5816 37 4057 20.91 5855 5602 36 3908 21.71 6070 5816

37 4057 20.91

5 Uplift 0.00 0.55 0.55 4813 4243 30 7763 10.92 4196 3682 26 6737 12.59 4645 4091

28 7484 11.33

6 No Wind (SWING 1) 0.00 0.55 0.55 3697 3228 23 5905 14.36 3170 2748 19 5028 16.87 3419 2975

21 5443 15.58

63

7 NESC Blowout 6PSF 0.39 0.55 0.67 4040 3662 25 5446 15.57 3566 3214 22 4780 17.74 3814 3449

23 5129 16.53

8 High Wind (SWING 3) 1.35 0.55 1.46 6132 5878 38 4028 21.06 5928 5675 36 3889 21.82 6132 5878

38 4028 21.06

9 Vibration Control 0.00 0.55 0.55 3697 3228 23 5905 14.36 3170 2748 19 5028 16.87 3419 2975

21 5443 15.58

10 Mean Annual Temperature 0.26 0.55 0.61 3732 3322 23 5485 15.46 3251 2875 20 4747 17.87 3481 3088

21 5099 16.63

11 NESC Deflection 0.00 0.55 0.55 3339 2903 20 5310 15.97 2884 2488 18 4551 18.64 3079 2665

19 4876 17.39

12 0 Deg F 0.00 0.55 0.55 4630 4077 28 7459 11.37 4009 3512 25 6425 13.20 4424 3889

27 7116 11.91

13 25 Deg F 0.00 0.55 0.55 4207 3692 26 6754 12.55 3608 3148 22 5759 14.73 3942 3451

24 6314 13.43

14 60 Deg F 0.00 0.55 0.55 3697 3228 23 5905 14.36 3170 2748 19 5028 16.87 3419 2975

21 5443 15.58

15 100 Deg F 0.00 0.55 0.55 3235 2808 20 5136 16.51 2802 2413 17 4414 19.22 2983 2578

18 4717 17.98

16 120 Deg F 0.00 0.55 0.55 3044 2633 19 4817 17.61 2655 2279 16 4169 20.35 2811 2421

17 4429 19.15

17 302 Deg F 0.00 0.55 0.55 2130 1798 13 3290 25.80 2115 1784 13 3264 26.00 2127 1796

13 3285 25.83

18 356 Deg F 0.00 0.55 0.55 2032 1708 12 3125 27.16 2018 1695 12 3102 27.37 2029 1706

12 3121 27.20

19 Maximum Operating 0.00 0.55 0.55 2130 1798 13 3290 25.80 2115 1784 13 3264 26.00 2127 1796

13 3285 25.83

Tension Distribution in Inner and Outer Materials

--------Weather Case------- | --Initial Condition- | --Final After Creep- | --Final After Load-- |

| Horiz. Tension (lbs) | Horiz. Tension (lbs) | Horiz. Tension (lbs) |

# Description | | | |

| Total Core Outer | Total Core Outer | Total Core Outer |

---------------------------------------------------------------------------------------------------

1 NESC Light 5284 2310 2974 4992 2462 2531 5284 2310 2974

2 GO 95 Light 4361 1827 2533 3920 2040 1880 4222 1893 2330

3 NESC Extreme Wind (250C) 4954 2278 2676 4632 2504 2128 4879 2336 2544

4 IID Extreme Wind 5816 2710 3106 5602 2859 2743 5816 2710 3106

5 Uplift 4243 1609 2634 3682 1750 1932 4091 1641 2449

6 No Wind (SWING 1) 3228 1455 1773 2748 1815 934 2975 1640 1336

7 NESC Blowout 6PSF 3662 1656 2005 3214 1985 1229 3449 1813 1636

8 High Wind (SWING 3) 5878 2742 3136 5675 2885 2790 5878 2742 3136

9 Vibration Control 3228 1455 1773 2748 1815 934 2975 1640 1336

10 Mean Annual Temperature 3322 1547 1775 2875 1919 956 3088 1739 1349

11 NESC Deflection 2903 1455 1448 2488 1893 594 2665 1700 965

12 0 Deg F 4077 1573 2504 3512 1746 1766 3889 1626 2264

13 25 Deg F 3692 1504 2188 3148 1758 1390 3451 1611 1841

14 60 Deg F 3228 1455 1773 2748 1815 934 2975 1640 1336

15 100 Deg F 2808 1462 1345 2413 1924 489 2578 1726 852

16 120 Deg F 2633 1486 1147 2279 1991 288 2421 1785 636

17 302 Deg F 1798 1798 0 1784 1784 0 1796 1796 0

18 356 Deg F 1708 1708 0 1695 1695 0 1706 1706 0

19 Maximum Operating 1798 1798 0 1784 1784 0 1796 1796 0

64

APPENDIX E. Sag & Tension Report-Shield Wire

Project Name : Project EE 500 -345 kV Transmission Line

Notes :

Typical 2007 NESC C2-2012 Criteria. File for PLS-CADD Created December 3 1, 2006 Version 8 . 10

Assumed: NESC Heavy Combined Ice and Wind Loading District ( Rule 250B)



Assumed Maximum Operating Temperature of 212ºF

Assumed 1" Extreme Ice {Non-NESC) Assumed Grade B C onstruction

<<Illustration of NESC provisions include>>

>Combined Ice and Wind District Loading NESC Heavy per Rule 250-13, Page 177

> Extreme Wind Loading per Rule 250C , Page 177, Coefficient 3 and Gust Response Factors per Equations in

Tables 250-2 and 250-3

> 90 MPH Basic Wind Speed, 3 Second Gust Wind Speed, Figure 250-2 Beginning on Page 180

> Grade B Construction "Method A " per Table 253- 1, Page 197 and Table 261-lA , Page 207

>Extreme Ice with Concurrent Wind Loading per Rule 250D, Page 179

> 1" Basic Ice Diameter with Concurrent 30 MPH Basic Wind Speed , Figure 250-3 Beginning on Page 184

> Cable Tension and Automatic Sagging Limit3 per Rule 2 61H1, Page 2 04

**** NOTE - Many experts consider these limits to be high and could lead to severe aeolian vibration ****

**** PLS recommends checking with your cable manufacturer and/or other standard3 f or recommended value3 ****

> Insulator Mechanic al Strengths per Rule 2 77 - Important Note for Strength Check :

**** NESC Rule 2 77 specifically exclude3 Rule 2 53 Load Factor3 f or checking the mechanical 3trength of insulator3 ****

**** This Criteria. checks Insulators f or ILL case using a Strength Factor of 1.0 applied to insulator

working load proper tie3.

**** When specifying the in3ulator strength propertie3 in Component3/In3ulat or3 in TOWER and PLS-POLE,

the manufacturer' s recommended load capacities shall be used per NESC Table 277-1. This is

normally the RTL and RCL values published by the non-ceramic insulator manufacturers. See

IEEE Std 1572 -2004 IEEE Guide f or Application of Compo3ite Line Post In3ulators for further

clarification. ****

Per Rule 277, the responsible engineer should decide what "proper allowance " i3 f or Rule3 2 50C and 250D

and modify load cases accordingly ****

**** User may prefer to add other specific load cases utilizing alternative Strength Factors ****

**** Coordination of Load Factor3, Strength Factor3, and Component 3trength properties is the responsibility of

the RESPONSIBLE ENGINEER ****

**** See Tech Note at http://www .powline.com/products / nesc insulators .html f or additional discussion ****

> Structure Load3 criteria include3 typical Full Structure DE cases

POWER LINE SYSTEMS, INC . IS NOT RESPONSIBLE FOR THE ACCURACY OF THE CONTENT HEREIN OR RESULTS OBTAINED FROM

ITS USE ON ANY PROJECT .

THIS FILE IS PROVIDED FOR ILLUSTRATION ONLY . CRITERIA SHOULD BE CHECKED AND MODIFIED AS NECESSARY BY AN

ENGINEER IN RESPONSIBLE CHARGE,

FAMILIAR WITH THE NESC AND LOCAL REQUIREMENTS or THE AREA IN WHICH THE PROJECT IS LOCATED, AND ITS

APPLICATION.

RESPONSIBLE ENG INEER SHOULD VERIFY EXTREME WIND , CONCURRENT ICE AND WIND , AND EXTREME ICE PARAMETERS FOR

THEIR APPLICABLE REGION .

RESPONSIBLE ENGINEER SHOULD VERIFY MAXIMUM OPERATING CONDITION FOR THEIR

APPLICABLE PROJECT RESPONSIBLE ENGINEER SHOULD VERIFY CONDITIONS AND FACTORS

USED FOR INSULATOR STRENGTH CHECKS RESPONSIBLE ENGINEER SHOULD ADD ANY

ADDITIONAL CRITERIA THAT MAY BE REQUIRED BEYOND THE NESC RESPONSIBLE ENGINEER

SHOULD REMOVE THIS DISCLAIMER AND MODIFY NOTES ABOVE AS APPLICABLE WHEN

ASSUMING CHARGE OF THIS CRITERIA

Section 114 from sti:uctwe 1121 to sti:uctw::e 11213, sta.J::t set 111 'SW-RT-A' , end set 111 'SW-RT-A'

Ca.b1e ' c:\usc:i:s\pub1ic\documents\p1s\p1s

cadd\examp1c::s\ca.b1c::s\3 8ehs ' , Ru1inq span

(ft ) 1209.1 Sagging data : Catena.ry j ft )

10251.3 , Ho i z . Ten3ion j lb3) 2798-:-6

Condition I Temperature j deg F) 60 Weather

ca3e f or final after creep 60 Deg F,

Equivalent to 0.2 (deg F) temperature

increa3e

Weather case for final after load NESC Light , Equivalent to 1.9 ( deg F) temperature increase

Ru1inq Span Saq Tension Report

lf eathei: Case------- Cab1e Load-- I ----R.S. Initia.1 Cond. ---- I -----R.S. Fina.1 Cond. ----- I -----R.S.

Fina.1 Cond. ----- 1 I --------Aft ei: Cireep------- I --------Aftei: Load--------

11 Description Hoi:. Vei:t Res. I Max. Hoi:i. Max R. S. I Max. Hoi:i. Max R. S. I Max. Hoi:i. Max R. S. -----Load----- ITens. Tens. Ten C Saq Tens. Tens. Ten C Saq ITens.

Tens. Ten C Saq --- (l..hs/ft )--- I(l..hs ) (l..hs ) %UL (ft) (ft) I(l..hs ) (l..hs ) %UL (ft) (ft) I(l..hs ) (l..hs )

%UL (ft) (ft)

1 NESC Light 0 .2 7 0 .2 7 0

.68

4812 4

684

3 1 6848 26

.70

4812 4

684

3 1 6848 26

.70

4812 4

684

3 1 6848 26

.70

65

2 GO 95 Light 0.24 0.27

0.36

353

0

345

5

23 9504

19.2 3

353

0

345

5

23 9504

19.2 3

352

1

344

7

23 948 2

19.2 8 3 NESC Extreme Wind j

2 50C)

0.47 0.27

0.54

402

8

3954 26 73 13

25.00

402

8

395

4

26 73 13

25.00

402

4

395

0

26 7306

25.03 4 I ID Extr eme Wind 0.65 0.27

0.70

464

9

456

7

30 6513 2

8.08

464

9

456

7

30 6513 2

8.08

4648 456

6

30 6512 2

8.08 5 Uplift 0.00 0.2 7

0.2 7

3468 335

9

23 12303

14.8 6

3468 335

9

23 12303

14.8 6

345

7

334

8

22 122 63

14.90 6 No Wind (SWING 1) 0.00 0.27

0.27

2

893

279

7

19 102 46

17.84

2

893

279

7

19 102 46

17.84

2

878

2

783

19 10193

17.93 7 NESC Blowout 6PSF 0 . 18 0 .27 0

.33

3

126

304

7

20 93 18

19.62

3

126

304

7

20 93 18

19.62

3

114

303

6

20 9283

19.69 8 High Wind (SWING 3 ) 0.62 0.27

0.68

456

7

448

7

30 6605 2

7.69

456

7

448

7

30 6605 2

7.69

456

6

448

5

30 6602 2

7.70 9 Vibration Control 0 .00 0 .2 7 0

.2 7

2

893

279

7

19 10246

17.84

2

893

279

7

19 10246

17.84

2

878

278

3

19 10193

17.93 10 Mean Annual

Temperature

0. 12 0.27

0.30

2932 2

846

19 9545

19. 15

293

2

2

846

19 9545

19. 15

291

9

2

834

19 9502

19.24 11 NESC Def lection 0.00 0.27

0.27

268

6

259

5

17 9506

19.2 3

268

3

2592 17 9495

19.2 5

267

0

257

9

17 9448

19.35 12 0 Deg F 0.00 0.27

0.27

337

8

327

1

22 11980

15.26

337

8

327

1

22 11980

15.26

33

65

325

8

22 11935

15.3 1 13 25 Deg F 0.00 0.2 7

0.2 7

3

166

306

3

2 1 1122 1

16.29

3

166

306

3

2 1 1122 1

16.29

3

151

304

9

20 11168

16.37 14 60 Deg F 0.00 0.27

0.27

2

893

279

7

19 102 46

17.84

2

893

279

7

19 102 46

17.84

2

878

2

783

19 10193

17.93 15 100 Deg F 0 .00 0 .27 0

.27

262

4

253

4

17 9282

19.69

261

8

252

9

17 9262

19.74

2

605

25

16

17 9216

19.84 16 120 Deg F 0.00 0.27

0.27

2

502

2

415

16 8847 2

0.66

249

6

2

410

16 8828 2

0.71

248

5

239

9

16 8787 2

0.80 17 302 Deg F 0 .00 0 .2 7 0

.2 7

176

7

1694 11 6207 29

.46

175

4

1682 11 6160 29

.69

174

9

167

7

11 6141 29

.78 18 356 Deg F 0.00 0.27

0.27

163

5

156

3

11 5725 3

1.95

162

2

155

0

11 5678 32

.21

161

8

154

6

11 5662 32

.3 1 19 Maximum Operating 0.00 0.27

0.27

176

7

169

4

11 6207 29

.46

175

4

168

2

11 6160 29

.69

174

9

167

7

11 6141 29

.78

66

APPENDIX F. Transmission Line Route (3-D) Partial

67

APPENDIX G. ASPEN Program-Fault Analysis

3-Phase Fault

Model Single-

Line Diagram

Summary of fault being displayed:

Prefault voltage: Flat Bus V=1 p.u.

Generator impedance: Subtransient

MOV iteration: [Off]

Enforce generator current limit [Off]

ANSI x/r ratio calculation [Off]

====================================================================================================

OUTPUT

1. Bus Fault on: 0 BUS8 345. kV 3LG

FAULT CURRENT (A @ DEG)

+ SEQ - SEQ 0 SEQ A PHASE B PHASE C PHASE

422.3@ 37.0 0.0@ 0.0 0.0@ 0.0 422.3@ 37.0 422.3@ -83.0 422.3@ 157.0

THEVENIN IMPEDANCE (OHM)

376.584+j-284.07 376.584+j-284.07 551.136+j-152.82

SHORT CIRCUIT MVA= 252.3 X/R RATIO= -0.7543 R0/X1= -1.9401 X0/X1= 0.53795

-----------------------------------------------------------------------------------------------------------------------------------

BUS 0 BUS8 345.KV AREA 1 ZONE 1 TIER 0 (PREFAULT V=1.000@ 0.0 PU)


VOLTAGE (KV, L-G) > 0.000@ 0.0 0.000@ 0.0 0.000@ 0.0 0.000@ 0.0 0.000@ 0.0 0.000@ 0.0

SHUNT CURRENTS (A) >

TO LOAD 0.0@ 0.0 0.0@ 0.0 0.0@ 0.0 0.0@ 0.0 0.0@ 0.0 0.0@ 0.0

FROM FICT. CURR. SOURCE 334.7@ -0.0 0.0@ 0.0 0.0@ 0.0 334.7@ 0.0 [email protected] 334.7@ 120.0

BRANCH CURRENT (A) TO >

0 BUS7 345. 1L 254.3@ -90.5 0.0@ 0.0 0.0@ 0.0 254.3@ -90.5 254.3@ 149.5 254.3@ 29.5

68

CURRENT TO FAULT (A) > 422.3@ 37.0 0.0@ 0.0 0.0@ 0.0 422.3@ 37.0 422.3@ -83.0 422.3@ 157.0

THEVENIN IMPEDANCE (OHM) > 471.711@ -37.0 471.711@ -37.0 571.93@ -15.5

Phase-to-Ground Fault

Summary of fault being displayed:

Prefault voltage: Flat Bus V=1 p.u.

Generator impedance: Subtransient

MOV iteration: [Off]

Enforce generator current limit [Off]

ANSI x/r ratio calculation [Off]

===================================================================================================

=

OUTPUT

2. Bus Fault on: 0 BUS8 345. kV 1LG Type=A

FAULT CURRENT (A @ DEG)


133.7@ 28.9 133.7@ 28.9 133.7@ 28.9 401.0@ 28.9 0.0@ 0.0 0.0@ 0.0

THEVENIN IMPEDANCE (OHM)

376.584+j-284.07 376.584+j-284.07 551.136+j-152.82

SHORT CIRCUIT MVA= 239.6 X/R RATIO= -0.5528 R0/X1= -1.9401 X0/X1= 0.53795

-----------------------------------------------------------------------------------------------------------------------------------

BUS 0 BUS8 345.KV AREA 1 ZONE 1 TIER 0 (PREFAULT V=1.000@ 0.0 PU)


VOLTAGE (KV, L-G) > 137.056@ 3.7 63.047@ 171.9 [email protected] 0.000@ 0.0 [email protected] 183.611@ 127.4

SHUNT CURRENTS (A) >

TO LOAD 230.3@ 3.7 105.9@ 171.9 [email protected] 0.0@ 0.0 [email protected] 308.5@ 127.4

FROM FICT. CURR. SOURCE 334.7@ -0.0 0.0@ 0.0 0.0@ 0.0 334.7@ 0.0 [email protected] 334.7@ 120.0

BRANCH CURRENT (A) TO >

0 BUS7 345. 1L 80.5@ -98.6 80.5@ -98.6 35.7@ -77.1 194.7@ -94.8 49.0@ 65.9 49.0@ 65.9

CURRENT TO FAULT (A) > 133.7@ 28.9 133.7@ 28.9 133.7@ 28.9 401.0@ 28.9 0.0@ 0.0 0.0@ 0.0

THEVENIN IMPEDANCE (OHM) > 471.711@ -37.0 471.711@ -37.0 571.93@ -15.5

-----------------------------------------------------------------------------------------------------------------------------------

69

APPENDIX H. MATLAB Program

PROGRAM: MATLAB, mathworks.com

DESIGNERS: ALEX TAKAHASHI & RK RAVURI:

MODEL: TRANSMISSION LINE 168 miles Long FOR EEE-500 Project:

PROGRAM LISTING clc clear all

disp('') disp(' --------------------------------------------------------------

') disp(' Designed By:') disp(' ALEX TAKAHASHI & RK RAVURI') disp(' TRANSMISSION LINE 168 miles Long FOR Project: EEE-500:') disp(' From: Bishop, CA. to Kramer Junction along Hwy-395') disp(' --------------------------------------------------------------

') disp(' ') disp('LoadPower, Pr = 200 MW ') disp('ACSR conductors are made up of 397,500-kcmil 26/7-strand') disp('Distances between conductors are:') disp('D12=27.2 ft. D23=27.2 ft. D13=54.4 ft.') disp('') TL=168; % transmission line length, mi VrLL=345*10^3; % line to line voltage, V Pr=200*10^6; % load power, Watts pf=0.95; % power factor, pf D12=27.2; % ft D23=27.2; % ft D13=54.4; % ft disp(' ') disp('Characteristics of ACSR 397,500-kcmil 26/7-strand, Table A.3,

A.8, and A.9') disp('do=0.783 outside diameter of conductor, inches') do=0.783; disp('ra=0.259 resistance, ohms/mi ') ra=0.259; disp('') disp('xa=0.441 inductive reactance, ohms/mi') xa=0.441; disp('') disp('xaa=0.1015 from table A.3, shunt capacitive reactance,

MegOhms*mi') xaa=0.1015; disp('') disp('xd=0.4289 from table A.8 based on calculated Deq, inductive

reactance') disp('spacing factor, MegOhms/mi') xd=0.4289;

70

disp('') disp('xdd=0.1049 from table A.9 based on calculated Deq, shunt

capacitive') disp('reactance spacing factor, MegOhms/mi') xdd=0.1049; disp(' ') disp(' *** EQUATIONS: ***') disp('equivalent spacing, Deq=(D12*D23*D13)^(1/3), feet') Deq=(D12*D23*D13)^(1/3) disp('VrLN=VrLL/(3)^(1/2), V') VrLN=VrLL/(3)^(1/2) disp('V') disp('thetap=acosd(pf) power factor angle') thetap=acosd(pf) thetar=(pf+sind(thetap)*i) % rectangular form of pf angle disp('Ir=Pr/(sqrt(3)*VrLL*pf) magnitude of the current, A') Ir=Pr/(sqrt(3)*VrLL*pf) % magnitude of the current disp('A') Irp=Ir/thetar % Ir with phase angle thetarangle=-1*(angle(thetar)*(180/pi)) % lagging disp('degrees lagging') disp('') raL=(ra*TL) disp('ohms') xaL=(xa*TL) disp('ohms') xaaL=(xaa/TL) disp('ohms') xdL=xd*TL disp('ohms') xddL=xdd/TL disp('ohms') disp('Xl=xaL+xdL ohms') Xl=xaL+xdL disp('ohms') disp('Zl=raL+Xl*i ohms') Zl=raL+Xl*i disp('ohms') disp('xcL=-1*(xaaL+xddL)*(10^6)*i ohms') xcL=-1*(xaaL+xddL)*(10^6)*i disp('ohms') disp('Yl=1/xcL Siemens') Yl=1/xcL disp('Siemens') disp('Yl magnitude is, Siemens') Ylmag=abs(Yl) disp('Siemens') disp('PropK = propagation constant') disp('') disp('PropK=(Yl*Zl)^(1/2)') PropK=(Yl*Zl)^(1/2) disp('Zc=(Zl/Yl)^(1/2)') Zc=(Zl/Yl)^(1/2)

71

disp('ohms') disp('Yc=1/Zc') Yc=1/Zc disp('Siemens') disp('') disp('a. A B C D constants of the Trans-Line') disp('A=cosh(PropK) ; where: PropK is the propagation constant') disp('B=Zc*(sinh(PropK))') disp('C=Yc*(sinh(PropK)) and D = A') disp('') A=cosh(PropK) B=Zc*(sinh(PropK)) C=Yc*(sinh(PropK)) D=A disp('') disp('[ABCD] = Matrix constants ABCD') [ABCD] = [A B;C D] disp('') disp('[VsLN ; Is]=[A B;C D]*[VrLN ; Irp]') [VsLNIs]=[ABCD]*[VrLN;Irp] disp('b. Sending end voltage') VsLN = VsLNIs(1,1) VsLNmag=abs(VsLN) VsLNangle=angle(VsLN)*(180/pi) % angle in degrees disp('') disp('c. Sending end current') disp('') Is = VsLNIs(2,1) Ismag=abs(Is) Isangle=angle(Is)*(180/pi) % angle in degrees disp('') disp('VsLL = (3)^(1/2)*(VsLN)') VsLL = (3)^(1/2)*(VsLN) VsLLmag=abs(VsLL) VsLLangle=angle(VsLL)*(180/pi) % angle in degrees disp('') disp('d. Sending end power factor, spf') disp('') thets = VsLNangle-(Isangle) spf=cosd(thets) disp('lagging') disp('') disp('e. Sending end power, SEP Watts') disp('') disp('SEP=(3)^(1/2)*(VsLLmag*Ismag*spf)') SEP=(3)^(1/2)*(VsLLmag*Ismag*spf) disp('') disp('f. Receiving end power, REP Watts') disp('') disp('') REP=(3)^(1/2)*(VrLL*Ir*pf) disp('REP=(3)^(1/2)*(VrLL*Ir*pf)') disp('Therefore, PL = power loss = SEP-REP, Watts')

72

disp('') disp('PL=SEP-REP') PL=SEP-REP disp('') disp('g. Efficiency, % n=REP/SEP') disp('') n=(REP/SEP)*100 disp('%') disp('') disp('h. % Voltage regulation, % VR=(((|VsLN|/|A|)-

/VrLN/)/|VrLN|)*100') disp('') VR=(((VsLNmag/A)-VrLN)/VrLN)*100 disp('%') disp('') disp('i. Sending-end charging current at no load is,') disp('Ic= 1/2*(Yl*VsLN), A') Ic= 1/2*(Yl*VsLN) disp('') disp('Ic magnitude and angle') Icmag=abs(Ic) disp('') Icangle=angle(Ic)*(180/pi) % angle in degrees disp('j. Receiving-end voltage "rise" at no load VrLNr is') disp('VrRLNr VsLN-Ic*Zl, V') VrLNr = VsLN-Ic*Zl disp('VrLNr magnitude and angle') VRLNmag=abs(VrLNr) VrLNrangle=angle(VrLNr)*(180/pi) disp(' Therefore, the line_to_line voltage at the receiving end

is,') disp(' VrLLr = (3)^(1/2)* VrLNr, V ') disp(' Converting VrLNr to VrLLr, there is a 30 degree phase

shift') disp(' Let: phase_shift = 30 degrees phase shift') disp('') phase_shift=30; ps=(cosd(phase_shift)+sind(phase_shift)*i);

VrLLr=(3)^(1/2)* VrLNr*ps disp('VrLLr magnitude and angle') VrLLrmag=abs(VrLLr); VrLLrangle=angle(VrLLr)*(180/pi) % angle in degrees

73

PROGRAM: MATLAB, mathworks.com

DESIGNERS: ALEX TAKAHASHI & RK RAVURI:

MODEL: TRANSMISSION LINE 168 miles Long FOR EEE-500 Project:

PROGRAM OUTPUT

LoadPower, Pr = 200 MW

ACSR conductors are made up of 397,500-kcmil 26/7-strand

Distances between conductors are:

D12=27.2 ft. D23=27.2 ft. D13=54.4 ft.

Characteristics of ACSR 397,500-kcmil 26/7-strand, Table A.3, A.8, and A.9

Do = 0.783 outside diameter of conductor, inches

ra = 0.259 resistance, ohms/mi

xa = 0.441 inductive reactance, ohms/mi

xaa = 0.1015 from table A.3, shunt capacitive reactance, MegOhms*mi

xd = 0.4289 from table A.8 based on calculated Deq, inductive reactance

spacing factor, MegOhms/mi

xdd = 0.1049 from table A.9 based on calculated Deq, shunt capacitive

reactance spacing factor, MegOhms/mi

*** EQUATIONS: ***

equivalent spacing, Deq = (D12*D23*D13)^(1/3), feet

Deq =

34.2699

VrLN=VrLL/(3)^(1/2), V

VrLN =

1.9919e+05

V

Thetap = acosd(pf) power factor angle

thetap =

18.1949

74

thetar =

0.9500 + 0.3122i

Ir = Pr/(sqrt(3)*VrLL*pf) magnitude of the current, A

Ir =

352.3114

A

Irp =

3.3470e+02 - 1.1001e+02i

thetarangle =

-18.1949

degrees lagging

raL =

43.5120

ohms

xaL =

74.0880

ohms

xaaL =

6.0417e-04

ohms

xdL =

72.0552

ohms

xddL =

6.2440e-04

ohms

Xl = xaL+xdL ohms

Xl =

146.1432

75

ohms

Zl = raL+Xl*i ohms

Zl =

4.3512e+01 + 1.4614e+02i

ohms

xcL=-1*(xaaL+xddL)*(10^6)*i ohms

xcL =

0.0000e+00 - 1.2286e+03i

ohms

Yl=1/xcL Siemens

Yl =

0.0000e+00 + 8.1395e-04i

Siemens

Yl magnitude is, Siemens

Ylmag =

8.1395e-04

Siemens

PropK = propagation constant

PropK = (Yl*Zl)^(1/2)

PropK =

0.0508 + 0.3486i

Zc = (Zl/Yl)^(1/2)

Zc =

4.2830e+02 - 6.2407e+01i

ohms

Yc=1/Zc

Yc =

0.0023 + 0.0003

Siemens

76

a. A B C D constants of the Trans-Line

A=cosh(PropK); where: PropK is the propagation constant

B=Zc*(sinh(PropK))

C=Yc*(sinh(PropK)) and D = A

A =

0.9411 + 0.0174i

B =

4.1802e+01 + 1.4352e+02i

C =

-4.7477e-06 + 7.9790e-04i

D =

0.9411 + 0.0174i

[ABCD] = Matrix constants ABCD

ABCD =

1.0e+02 *

0.0094 + 0.0002i 0.4180 + 1.4352i

-0.0000 + 0.0000i 0.0094 + 0.0002i

[VsLN ; Is] = [A B;C D]*[VrLN ; Irp]

VsLNIs =

1.0e+05 *

2.1722 + 0.4689i

0.0032 + 0.0006i

b. Sending end voltage

VsLN =

2.1722e+05 + 4.6893e+04i

VsLNmag =

2.2223e+05

VsLNangle =

12.1817

77

c. Sending end current

Is =

3.1593e+02 + 6.1216e+01i

Ismag =

321.8085

Isangle =

10.9659

VsLL = (3)^(1/2)*(VsLN)

VsLL =

3.7624e+05 + 8.1221e+04i

VsLLmag =

3.8491e+05

VsLLangle =

12.1817

d. Sending end power factor, spf

thets =

1.2158

spf =

0.9998

lagging

e. Sending end power, SEP Watts

SEP = (3)^(1/2)*(VsLLmag*Ismag*spf)

SEP =

2.1450e+08

f. Receiving end power, REP Watts

REP =

200000000

REP = (3)^(1/2)*(VrLL*Ir*pf)

Therefore, PL = power loss = SEP-REP, Watts

78

PL= SEP-REP

PL =

1.4497e+07

g. Efficiency, % n = REP/SEP

n =

93.2416%

h. % Voltage regulation, % VR = (((|VsLN|/|A|)-/VrLN/)/|VrLN|)*100

VR =

18.5158 - 2.1862i %

i. Sending-end charging current at no load is,

Ic = 1/2*(Yl*VsLN), A

Ic =

-19.0844 +88.4053i

Ic magnitude and angle

Icmag =

90.4417

Icangle =

102.1817

j. Receiving-end voltage "rise" at no load VrLNr is

VrRLNr VsLN-Ic*Zl, V

VrLNr =

2.3097e+05 + 4.5836e+04i

VrLNr magnitude and angle

VRLNmag =

2.3548e+05

VrLNrangle =

11.2242

Therefore, the line_to_line voltage at the receiving end is,

VrLLr = (3)^(1/2)* VrLNr, V

79

Converting VrLNr to VrLLr, there is a 30 degree phase shift

Let: phase_shift = 30 degrees phase shift

VrLLr =

3.0667e+05 + 2.6878e+05i

VrLLr magnitude and angle

VrLLrangle =

41.2242

>> Published with MATLAB® R2012b

http://www.mathworks.com/products/matlab

80

References

[1] Dr. Turan Gonen. Electric Power Transmission System Engineering Analysis

and Design, CRC Press, New York, 2nd ed., 2009

[2] EDSA Advance Transmission Line Parameters and Electric & Magnetic Field

Computation Program

[3] PLS-CADD Power Line Systems – Computer Aided Design and Drafting

[4] Robert J. Alonzo, Electrical Codes, Standards, Recommended Practices and

Regulations: An Examination of Relevant Safety Considerations,.2009

[5] IEEE Guide for Preparation of a Transmission Lines Design Criteria Document,

2011

[6] RUS Bulletin 1724E-200, 2004

[7] Electrical Power Transmission: background and Policy Issues, Congressional

Research Services, 2009

[8] Congressional Research Service, “Electric Power Trends: Background & Policy

issues” Congressional Research Service, Doc. No. R40511, Library of Congress,

101 Independence Ave. SE Washington DC. 20540, Dated April 14th, 2009.

[9] WestPower Incorporated, San Leandro, California

(Contributor of transmission line construction photographs.)

http://www.amazon.com/Electrical-Standards-Recommended-Regulations-ebook/dp/B003L783ZS/ref=sr_1_1?s=digital-text&ie=UTF8&qid=1376284839&sr=1-1&keywords=Electrical+Codes%2C+Standards%2C+Recommended+Practices+and+Regulations%3A+An+Examination+of+Relevant+Safety+Considerations

http://www.amazon.com/Electrical-Standards-Recommended-Regulations-ebook/dp/B003L783ZS/ref=sr_1_1?s=digital-text&ie=UTF8&qid=1376284839&sr=1-1&keywords=Electrical+Codes%2C+Standards%2C+Recommended+Practices+and+Regulations%3A+An+Examination+of+Relevant+Safety+Considerations

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