Proceso de Diseño de Líneas de Transmisión

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)

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 1
1 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 1
1 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
1
2 0
1
2 0
1.0 0
I
( )( 3 )
( ) ( 3 )
a
f f g
f
f f g
Z Z Z Z Z
Z 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
1
0 2
1
0 2
1.0 0
Ia
Z Z
Z
Z Z
Ð




0
2 1
0 2
I I
a a
Z
Z Z
  

2
0 1
0 2
I I
a a
Z
Z Z
  

The actual fault currents could be obtained by using the matrix equation as shown
below:
[
𝐼𝑎𝐹
𝐼𝑏𝐹
𝐼𝑐𝐹
] = [
1 1 1
1 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 1
1 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
af
I 0

bF cF
I I
 
bc b c F bF
V 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.
a0
I 0

1 2
I I
a 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 1
1 𝑎2
𝑎
1 𝑎 𝑎2
] x [
𝐼𝑎0
𝐼𝑎1
𝐼𝑎2
] = [
1 1 1
1 𝑎2
𝑎
1 𝑎 𝑎2
] x [
0
𝐼𝑎1
−𝐼𝑎1
]
Fault line currents are expressed below:
I 0
af 
1
I 3I
bf a
j
 
1
I 3I
bf a
j

The sequence voltages for the sequence networks can be found by inspecting Figure 3.8.
a0
V 0

a1 1 a1
V 1 – Z I

a2 2 a2 2 a1
V Z I Z I
  
The fault voltages for each phase could be derived by the following equation:
[
𝑉𝑎𝐹
𝑉𝑏𝐹
𝑉𝑐𝐹
] = [
1 1 1
1 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:
a0
I 0

a2
I 0


26
1
1
I f
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 1
1 𝑎2
𝑎
1 𝑎 𝑎2
] x [
0
𝐼𝑎1
0
]
The fault line currents are then expressed as follows:
1
I f
af
f
V
Z Z


0
2
1
1
240
I I f
bf a
f
V
a
Z Z
Ð
 

0
1
1
120
I I f
cf a
f
V
a
Z Z
Ð
 

The following sequence voltages for the sequence networks can be found by inspecting
Figure 3.10 above.
a0
V 0

a1 a1
V Z I
f

a2
V 0

The fault voltages for each phase can be derived as follows:
[
𝑉𝑎𝐹
𝑉𝑏𝐹
𝑉𝑐𝐹
] = [
1 1 1
1 𝑎2
𝑎
1 𝑎 𝑎2
] x [
𝑉𝑎0
𝑉𝑎1
𝑉𝑎2
] = [
1 1 1
1 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
ResistanceInductance
reactance
Capacitance
reactance
EfficiencyVoltage
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 =0.458Ω
𝑚𝑖𝑙𝑒
⁄ 𝑥𝑑 = 0.3773Ω
𝑚𝑖𝑙𝑒
⁄
𝑥𝑎
′
= 0.1057MΩ
𝑚𝑖𝑙𝑒
⁄ 𝑥𝑑
′
=0.0922MΩ
𝑚𝑖𝑙𝑒
⁄
The inductive reactance is
𝑥𝐿 = 𝑥𝑎 + 𝑥𝑑 = 0.458+0.3773= 0.8353Ω
𝑚𝑖𝑙𝑒
⁄
The capacitive reactance is
𝑥𝐶 =𝑥𝑎
′
+ 𝑥𝑑
′
= 0.1057+ 0.0922= 0.1979 𝑀 Ω
𝑚𝑖𝑙𝑒
⁄
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 = j
1
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°) = 2.1x10−3
Ð78.8671°
The propagation constant of the line with the line length of 168 miles is calculated as
follows:
g(ℓ) = (2.068x10−3
Ð85.81°) 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:
[
𝑉𝑠
𝐼𝑠
] = [
𝐴 𝐵
𝐶 𝐷
] x [
𝑉𝑅
𝐼𝑅
]
The polar form of the matrix equation is:
[
𝑉𝑠
𝐼𝑠
] = [
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
2
2 5
0
241
( 25) ( ) 10
C
r
P f V V
D
kW
km


   
     
   
  


C
P 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

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)

50
APPENDIX A. Plan & Profile Report (Partial)

55
APPENDIX B. PLS-CADD Load Cases Report
PLS-CADD Version 12.30x64
Project Name: 'c:westpoweralex 345alex345-5.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: 'cAlexT 345alex345-5.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
**** 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:3-10-12old dcablesacsribis_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
>Combined Ice and Wind District Loading NESC Heavy per Rule 250-13, Page 177
> Extreme Wind Loading per Rule 250C , Page 177, Coefficient3 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 277 specifically exclude3 Rule 253 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:spub1icdocumentsp1sp1s
caddexamp1c::sca.b1c::s3 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----- I
Tens. Tens. Ten C Saq T
ens. Tens. Ten C Saq I
Tens.
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
19.23
353
0
345
5
23 9504
19.23
352
1
344
7
23 9482
19.2 8
3 NESC Extreme Wind j
250C)
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 Extreme 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 10246
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. 1
2 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
15.31
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 10246
17.84
2
878
2
783
19 10193
17.93
1
5 100 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
.31
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@ 0.0 334.7@-120.0 334.7@ 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 76.441@-166.6 0.000@ 0.0 228.242@-119.3 183.611@ 127.4
SHUNT CURRENTS (A) >
TO LOAD 230.3@ 3.7 105.9@ 171.9 128.4@-166.6 0.0@ 0.0 383.5@-119.3 308.5@ 127.4
FROM FICT. CURR. SOURCE 334.7@ -0.0 0.0@ 0.0 0.0@ 0.0 334.7@ 0.0 334.7@-120.0 334.7@ 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')

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