OVERHEAD DESIGN MANUAL...2020/07/14 · from type of construction used refer Overhead Construction Manual). A ground line profile is now required. Using trigonometry, we convert the

© ENERGEX 2020 MANUAL 00302 VERSION 13

OVERHEAD DESIGN MANUAL

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© COPYRIGHT 2015 ENERGEX This drawing must not be reproduced in part or whole without written permission from ENERGEX

Table of Contents

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Section Title 0 Quick Reference Guide

1 Line Design Overview

2 Poles

3 Stays

4 Poletop Constructions

5 Clearances

6 Mechanical Loads

7 Stringing Tables

8 Sag Tension Temperature Charts

9 Cable Data

10 Earthing

11 Policy and Practice

12 Glossary and Index

13 Amendment Record


© ENERGEX 2015 MANUAL 00302


Section 0 – Quick Reference Guide



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REFERENCE INDEX SECTION SUB-SECTION TITLE

LINE DESIGN OVERVIEW 1 1 TABLE OF CONTENTS 1 2 GENERAL DESIGN APPROACH AND LIMIT STATES 1 3 LOAD FACTORS AND WIND PRESSURES 1 4 COMPONENT STRENGTH FACTORS 1 5 LINE TEMPERATURE CASES 1 6 LINE DESIGN PROCESS 1 7 WORKED EXAMPLE POLES 2 1 TABLE OF CONTENTS 2 2 POLES SELECTION GUIDELINES 2 3 WOOD POLE DATA-CURRENT TYPES 2 4 WOOD POLE DATA-OLDER TYPES 2 5 CONCRETE POLE DATA 2 6 REINSTATED (NAILED) WOOD POLES-CURRENT TYPES 2 7 REINSTATED (NAILED) WOOD POLES-OLDER TYPES 2 8 BENDING MOMENT CAPACITY OF TIMBER POLES 2 9 POLE INSPECTION, ALIGNMENT & PEGGING 2 10 WOOD POLE SPECIES - STRENGTH GROUP IDENTIFICATION 2 11 WORKED EXAMPLE - POLE SIZING & FOUNDATION SELECTION 2 12 ENGINEERING BACKGROUND STAYS 3 1 TABLE OF CONTENTS 3 2 GROUND STAYS 3 3 POLE AND SIDEWALK STAYS 3 4 STAY POSITIONING 3 5 ENGINEERING BACKGROUND POLETOP CONSTRUCTION

4 1 TABLE OF CONTENS 4 2 CONSTRUCTION SELECTION GUIDELINES 4 3 LV & 11kV MIMIC DIAGRAMS & LAYOUT GUIDE - INTERMEDIATE & TENSION CONSTRUCTION ABC 4 4 LV MIMIC DIAGRAMS & LAYOUT GUIDE - INTERMEDIATE & TENSION CONSTRUCTION AAC/ACSR/COPPER 4 5 11kV LAYOUT GUIDE - INTERMEDIATE & TENSION CONSTRUCTION CCT 4 6 11kV MIMIC DIAGRAMS & LAYOUT GUIDE - INTERMEDIATE CONSTRUCTION AAC/ACSR/COPPER


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REFERENCE INDEX.....SECTION SUB-SECTION TITLE.....

4 7 11kV MIMIC DIAGRAMS & OPEN WIRE LAYOUT GUIDE - TENSION CONSTRUCTION AAC/ACSR/COPPER 4 8 33kV MIMIC DIAGRAMS & OPEN WIRE LAYOUT GUIDE - INTERMEDIATE CONSTRUCTION AAC/ACSR/COPPER 4 9 33kV MIMIC DIAGRAMS & OPEN WIRE LAYOUT GUIDE - TENSION CONSTRUCTION AAC/ACSR/COPPER 4 10 LAYOUT GUIDES - ADSS & PILOT CABLE CONSTRUCTIONS 4 11 LAYOUT GUIDES - OPGW CONSTRUCTIONS 4 13 LAYOUT GUIDES - OHEW CONSTRUCTIONS 4 13 INSULATOR SELECTION GUIDELINES 4 14 INSULATOR SELECTION4 15 VIBRATION PROTECTION4 16 BRIDGING - LV 4 17 PHASING4 18 LINE FAULT INDICATORS 4 19 POLE MOUNTED RECLOSERS, LOAD TRANSFER SWITCHES, SECTIONALISERS & DSA SCHEMES 4 20 ENGINEERING BACKGROUND

CLEARANCES 5 1 TABLE OF CONTENTS 5 2 SUMMARY OF CLEARANCE REQUIREMENTS 5 3 DISTRIBUTION & SUB TRANSMISSION CLEARANCES FROM GROUND & STRUCTURES 5 4 SERVICE CABLE CLEARANCES FROM GROUND & STRUCTURES 5 5 INTERCIRCUIT CLEARANCES5 6 KINGBOLT SPACING SUPERCIRCUIT / SUBCIRCUIT 5 7 STAY WIRES 5 8 STREETLIGHTS 5 9 COMMUNICATIONS - BROADBAND & PILOT CABLE 5 10 POWERLINK5 11 QUEENSLAND RAILWAYS5 12 MAIN ROADS

MECHANICAL LOADS 6 1 TABLE OF CONTENTS 6 2 ABC6 3 CCT6 4 SINGLE BARE Al. CONDUCTOR, NO WIND 15°C 6 5 SINGLE BARE Al. CONDUCTOR, 900Pa WIND 15°C 6 6 SINGLE BARE COPPER CONDUCTOR, NO WIND 15°C 6 7 SINGLE BARE COPPER CONDUCTOR, 900Pa WIND 15°C


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6 8 STEEL CONDUCTOR 6 9 COMMUNICATION CABLE 6 10 CONDUCTOR WIND LOAD ON STRAIGHT LINE INTERMEDIATE POLES 6 11 OPTUS BBCC 6 12 TELSTRA BBCC 6 13 ENGINEERING BACKGROUND STRINGING TABLES 7 1 TABLE OF CONTENTS 7 2 GUIDELINES 7 3 TABLE 26 & 42 STEEL 7 4 TABLE 440 - 880 LVABC 7 5 TABLE 220 - 880 CCT 7 6 TABLE 110 - 880 AAC 7 7 TABLE 42 & 65 ACSR 7 8 TABLE 110 - 880 PILOT CABLE 7 9 ADSS & OPGW 7 10 BLOWOUT TABLES 7 11 WORKED EXAMPLES 7 12 ENGINEERING NOTES TENSION TEMPERATURE CHARTS

8 1 TABLE OF CONTENTS 8 2 SAG TENSION TEMPERATURE CURVES TABLE - AAC 8 3 SAG TENSION TEMPERATURE CURVES TABLE - ACSR 8 4 SAG TENSION TEMPERATURE CURVES TABLE - 35mm² HVABC 8 5 SAG TENSION TEMPERATURE CURVES TABLE - 120mm² HVABC 8 6 SAG TENSION TEMPERATURE CURVES - 4C 95mm² LVABC 8 7 SAG TENSION TEMPERATURE CURVES - 2C 95mm² LVABC 8 8 SAG TENSION TEMPERATURE CURVES TABLE - PILOT 8 9 SAG TENSION TEMPERATURE CURVES - CCT 8 10 EXPLANATORY NOTES CABLE DATA

9 1 TABLE OF CONTENTS. 9 2 CABLE SELECTION GUIDELINES 9 3 ELECTRICAL RATINGS 9 4 MECHANICAL PROPERTIES


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9 5 BROADBAND COMMUNICATIONS CABLE ID 9 6 ENGINEERING BACKGROUND EARTHING

10 1 TABLE OF CONTENTS 10 2 METALWORK AT GROUND LEVEL 10 3 APPLICATION GUIDELINES AND TELSTRA PLANT AND HV EARTHING (

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MainsDes – Mains Design Application

MainsDes is the Energex mains design application for distribution line design.

Information produced from this Application supersedes that currently compiled in the Overhead Design Manual. The graphical output produced in the Layout Guides is more comprehensive than the tables compiled in the Design Manual. Designers who have access to the MainsDes application shall use this application as the primary design tool.

External designers who do not have access to MainsDes shall continue to use the information in the Overhead Design Manual.


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Layout Guides

This tool includes all current layout guide information for distribution pole top constructions, providing graphical results of allowable span lengths with respect to deviation angles for the conductor and stringing table or percent of conductor minimum breaking load.

Assumptions used:

Wind span = Weight span.

Span Length = Mean Equivalent Span (MES).

Crossarm bisects the deviation angle.

All calculations are based on either Working Stress Design or Limit state Design.

Each pole top construction code may be selected from the dropdown list or typed into the box.

The selected construction may be only used within the unshaded area of the graph.

Tips: Always click the recalculate button whenever you change your

selection. By clicking on the icons beside the construction and conductor, further detail and images are provided.

Sag Tension

This tool allows the designer to determine conductor sags and tensions under various selected operating conditions. Maximum Working wind pressures is defaulted to 500Pa and for Limit State it is 900Pa. These can be modified but it is recommended only advanced users who understand the calculation modify this value. Blowout Parameters (vertical sag, Blowout Angle and Midspan Blowout are always calculated at 500Pa wind regardless of the calculation Type

Tips: Blowout angle is measured from the vertical. For multiple span calculations, untick the MES=Span box and add individual spans as required to calculate the MES.

Current Ratings

This tool allows the designer to determine the conductor temperature for a given current and alternatively, for a given conductor temperature, the load current is calculated based on the conditions criteria chosen.

Constructions

This tool provides images of all distribution constructions including design detail.

Conductors

This tool provides manufacturer’s data of the selected conductor.

Insulators

MainsDes InformationUncontrolled Document when Printed

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This tool provides images of all distribution insulators with supporting design detail including suitability for coastal or polluted areas.

Transformers

This tool provides images of all pole top distribution transformers including design detail.

LV Services

This tool provides sag information for a selected service cable over a range of span lengths.

When installed to the sags shown in the table, the maximum working tension (with 500 pa wind load) will not exceed 1kN.

Mechanical Forces

This tool provides Everyday Tension (EDT), Serviceability State (SST) and Limit State (LST) loads per conductor attachment for the selected conductor type and stringing table, or percent conductor minimum breaking load over a range of deviation angles.

Full termination loads are also provided.

SST Calculations are based on 500Pa wind pressure and Maximum working methodology

LST Calculations are based on 900Pa wind pressure and Limit State working methodology as per AS/NZS7000

Pole Strength Calculator

This tool provides information on residual wood pole strengths based on inspection data. It provides maximum allowable EDT, SST and LST tip loads for the pole based on its current condition and it also allows for wind load on the pole.

Note, for design purposes, only the EDT & LST values are to be used to determine the remaining design strength of the pole


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MANUAL 00302


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LINE DESIGN OVERVIEW GENERAL DESIGN APPROACH AND LIMIT STATES

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DESIGN CONSIDERATIONS AND LOAD CASES

At distribution voltages, overhead line design tends to consist of both simple structural engineering and electrical engineering. The two main technical aspects to the design of overhead distribution lines are: 1. ensuring that the mechanical load forces do not exceed the

strength of the structures or other components, and 2. ensuring that there are adequate clearances—between the

conductors and the ground or from other objects in the vicinity of the line, as well as between the various phase conductors and circuits themselves so that clashing does not occur.

The line must comply with these requirements over the full design range of weather and load conditions that could be reasonably encountered—when the line is cold and taut, when at its maximum design temperature and consequently when conductor sag is at a maximum, and under maximum wind conditions. The load conditions to be considered for Energex lines are set out in the following sections, where applicable wind pressures, temperatures and load factors are listed.

LIMIT STATES For structural integrity to be maintained the structure strength must always exceed the applied mechanical load, otherwise the line passes beyond the limit of its intact state to a damaged state or failed state. Also, the loads should not cause the line to become unserviceable in some way, e.g. if loads caused excessive deflection of a structure, causing clearances to be reduced below their design limits, or conductors are deformed by excessive loading though not actually broken.

INTACT STATE

DAMAGED STATE

FAILED STATE

Serviceability Limit

Ultimate Strength Limit

This may be expressed by the following general limit state equation:

φRn > effect of loads (γx Wn + Σ γx X) (i.e. strength > applied loading)

where: φ = the strength factor, which takes into account variability of the

material, workmanship, maintenance regime etc. Rn = the nominal strength of the component γx = the load factor, taking into account the variability of the load,

importance of structure, dynamics etc. Wn = wind load X = the applied loads pertinent to each loading condition

In limit state design, strength factors and load factors take into account statistical variations in loads and material properties to achieve a desired level of reliability.

CLEARANCES

STRUCTURAL LOADING


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Thus, the Strength Limit equation used within Energex, which pertains to loading under short-term (3s) wind gusts, with the appropriate load factors applied, may be expressed as follows: φRn > 1.0 Wn + 1.1 Gs + 1.25 Gc + 1.25Ftw where: Wn = effect of wind load on structure Gs = vertical downloads due to the self weight of structure + fittings Gc = vertical downloads due to conductors Ftw = conductor tension loads under maximum wind conditions (G indicates loads due to action of gravity; W indicates loads due to action of wind.) Note that the limit state equation is not a simple arithmetic equation. The loads include various vector components—vertical, horizontal longitudinal and horizontal transverse. However, for simple distribution lines, downloads are often relatively minor and are not a significant contribution to an overturning moment on the pole, so are often ignored. Note, too, that the structure components have different strengths in different directions and under different actions, e.g. compression, tension, shear or torsion. Apart from the Maximum Wind Strength Limit, Energex commonly also requires checking of the Everyday Limit, which addresses the effect of sustained (no wind) loading, primarily due to conductor everyday tension. This is particularly appropriate with timber and composite fibre components, which may deflect or deform under a sustained load. This limit state, with appropriate load factors applied, may be expressed as:

φRn > 1.1 Gs + 1.25 Gc + 1.1Fte

where:

Fte = conductor tension loads under everyday (no wind) conditions

This limit state approach to overhead design has been used widely in Australia since 1999. It is a rationalisation of the earlier working stress method, which applied a general factor of safety that was somewhat arbitrary in its derivation. Limit state design uses higher, more realistic wind loads (aligned with AS/NZS 1170 wind code), and material strength factors more closely aligned with reliability of performance. It takes a reliability-based (acceptable risk of failure) approach. Based on this approach, Energex applies an Average Recurrence Interval (ARI) of 50 years to determine design wind pressures for normal distribution lines. The following sections present design wind loads, load factors, strength factors and design temperatures to be used for various situations and load cases. AS/NZS 7000:2010 also sets out other limit states that designers may need to check where relevant, such as:

failure containment or broken wire condition (where one phase conductor breaks on one side of a strain point, so that the loads applied are then out of balance)

maintenance and construction loading snow and ice loading seismic loading torsional loading maximum wind uplift.

PRACTICAL APPLICATION OF LIMIT STATE EQUATIONS This manual presents tables of pole strengths in section 2. Mechanical loads applied by conductors are presented in section 6. These tables already incorporate the various load and component strength factors. This allows designers to easily compare loads with strength in order to check pole sizing and the need for stays.


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LOAD FACTORS

LOAD CASE

HORIZONTAL CONDUCTOR

FORCES

WIND LOAD ON

STRUCTURE

VERTICAL LOADS

CONDUCTORS STRUCTURE

Ft Wn Gc Gs

No Wind 1.1 _ 1.25 1.1

Wind 1.25 1.0 1.25 1.1 Refer AS/NZS 7000:2010 Table 7.3 for additional details.

DESIGN WIND PRESSURES

COMPONENT DESIGN PRESSURE

Conductors 900Pa

Round Poles 1300Pa

Flat Surfaces (Projected Area)

1500Pa

Notes 1. Wind pressures are generally based upon synoptic wind events since the entire

Energex franchise area lies within ‘coastal’ zone - Refer AS/NZS 7000:2010 Appendix B and AS/NZS 1170.2 for additional details. Refer also Handbook to AS/NZS 7000 HB 331:2012Table 7.1.

2. In general, span reduction factors are not used within Energex distribution design for the sake of simplicity. However, their use may be warranted for very large spans, say in excess of 200m.

3. The above wind pressures correspond to a wind speed of 139km/h. The various pressures listed are due to the different drag coefficients of the various components.


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LINE DESIGN OVERVIEW COMPONENT STRENGTH FACTORS

POLE SERVICEABILITY NOTE ADDED

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COMPONENT STRENGTH FACTORS

PART OF OVERHEAD LINE COMPONENT LIMIT STATE

STRENGTH FACTOR

φ

Wood structures preserved by full length treatment

Pole Strength 0.72

Serviceability 0.4#

Crossarm Strength 0.72

Serviceability 0.4

Wood structures not preserved by full length treatment

Pole Strength 0.50

Serviceability 0.30

Crossarm Strength 0.50

Serviceability 0.30

Concrete structures Pole Strength 0.9 (1.0*)

Steel structures Pole or crossarm Strength 0.9

Composite Fibre Structures Pole or crossarm Strength 0.75

Serviceability 0.30

Stays

Cable Strength 0.80

Cable members Strength 0.70

Anchors Strength 0.50

Conductors Strength 0.90

Serviceability 0.50

* 1.0 can be used for the Energex standard range of Rocla Reinforced poles # Refer Sheet 2-12-1 for more detail on Pole Serviceability factors used in

Energex

PART OF OVERHEAD LINE COMPONENT LIMIT STATE

STRENGTH FACTOR

φ

Fittings and pins—forged or fabricated Strength 0.95

Fittings—cast Strength 0.90

Fasteners Bolts, nuts, washers Strength 0.90

Porcelain or glass insulators Strength 0.95

Synthetic composite suspension or strain insulators Strength 0.5

Synthetic composite line post insulators Strength

0.9 (max. design

cantilever load)

Foundations relying on strength of soil—conventional soil testing Strength 0.6

Foundations relying on strength of soil—empirical assessment of soil Strength 0.5

Notes 1. Refer AS/NZS7000:2010 Table 6.2 for additional details. 2. Serviceability limit – ‘No Wind’ Condition.

Strength limit – ‘Wind’ Condition.


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LINE DESIGN OVERVIEW LINE TEMPERATURE CASES


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LINE TEMPERATURE CASES

SITUATION TEMP WHEN USED

Standard (Reference) Temperature 15°C Reference temperature for conductor stringing tables

Max. Design Temp. (Hot)

Standard Bare Mains (see Note 1) 75°C

Checking clearance from ground or objects below the line

LVABC, CCT 80°C

HVABC (catenary) 50ºC

New 33kV Line 110°C

OHEW, OPGW 40°C

PILOT, ADSS, BBCC 40°C

Min. Temp. (Cold) 5°C Checking clearance from objects above the line

Uplift

Standard 5°C Checking for uplift forces, esp. on intermediate structures

Western Areas 0°C

Subcircuit

Below standard bare or insulated mains (Winter Night Rating)

15°C Checking intercircuit clearance—hot supercircuit above and cool subcircuit below

Below new 33kV line

designed for 110°C operation (Summer Day Rating)

35°C

SITUATION TEMP WHEN USED

Blowout 30°C Checking horizontal line displacement (sideways ‘sag’) under 500Pa wind force

‘No Wind’ Load Condition 15°C Calculating sustained loads

‘Wind’ Load Condition 15°C Calculating loads under maximum wind condition

Midspan Conductor Clearances 50°C

Checking interphase conductor spacing to avoid clashing

Notes 1. Many older lines were designed to lower temperatures, commonly 55°C. 2. See also Section 1.6 sheet 7.

HOT

COLD

HOT

COOL

PLAN

COOL

COOL

WARM

REF.

COLD


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OVERVIEW OF DISTRIBUTION LINE DESIGN PROCESS

In general, design of an overhead line follows the steps shown opposite (with variations as necessary to suit the design). It should be noted that the process is iterative, ie the designer may make some initial assumptions, eg as to pole height and size, which may later need to be amended as the design is checked and gradually refined. Various options will be tried until a final optimum arrangement is formulated.

Determine Design Inputs/Parameters

Select Route

Select Conductor Type

‘Survey’ Route and Draw Ground Line Profile

Select Structure and Pole-top Construction Types

Select Stringing Tension and Basic Span Length

Nominate Pole Positions

Nominate Strain Poles, Pole Heights and Circuit Attachment Heights

Draw Circuit Profile

Check Vertical Clearances

Check for Uplift

Check Horizontal Clearances

Check Structure Capacities Matches Mechanical Forces

Nominate Fittings and Other Requirements

Design Satisfactory?

YES

Document Design

NO


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1. DETERMINE DESIGN INPUTS/PARAMETERS

Assemble all relevant requirements, constraints and background information, such as:

customer requirements planning requirements existing and proposed schematics future development statutory authority (eg local authority, main roads, railways, waterways,

environmental) requirements regarding alignments, types of construction and clearances

coordination with other services integration with lighting design survey/site information maps.

This information should be placed on file or documented in an appropriate manner.

2. SELECT ROUTE

When selecting the route of the overhead line, factors to be considered include:

cost – generally the shorter the route the cheaper it will be access to line and poles servicing lots/properties, present and future disruption to environment, vegetation or other services community acceptance obtaining approvals requirement for easements – lines on public lands are preferred ease of excavation for pole foundations.

3. SELECT CONDUCTOR

Conductor selection should be carried out in accordance with Section 9.2 ‘Cable Selection Guidelines’, planning requirements and any other applicable ENERGEX standards. Factors to be considered include: voltage whether the line is a main ‘trunk’ or a ‘spur’ load (present and future) – current-carrying capacity, voltage drop,

losses fault levels and protection local conditions – pollution, fires, vegetation line design temperature stringing tension.

4. SURVEY & DRAW GROUND LINE PROFILE

Line profiling is often necessary for lines traversing uneven ground. Where ground is flat or evenly sloping, profiling may not be necessary. The designer may be able to check ground clearances by simply deducting the sag in the longest span from the average height of the supports at either end.

Other reasons for line profiling include: checking clearances from structures such as ‘skip’ poles or street lights checking ground clearances where the heights of the two supports for a

conductor span differ markedly determining inter-circuit clearances on long multi-circuit spans (king bolt

spacings may need to be adjusted), typically >100m checking for uplift forces on structures determining vegetation clearing requirements.


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The ground line profile is plotted from survey data for the line route, typically using the following scales:

Horizontal: 1:1000 (1mm = 1m) Vertical: 1:200 (5mm = 1m)

The survey data may consist of distance and slope measurements for various segments of ground, between which the ground is assumed to slope evenly. These should be converted to distance (chainage) and RL (reduced level) measurements, to facilitate plotting.

HD = SD cos

≈ SD if < 10°

VD = SD sin

where: SD = Slope Distance VD = Vertical Distance HD = Horizontal Distance

On the ground line plot, features such as buildings, fences, gullies, pole ‘no-go’ areas, roads, large trees, obstacles and waterways should be shown.

An offset line is then drawn above and parallel to the ground line (GL), according to the minimum vertical clearances that apply. For example, for a HV line crossing a carriageway, the GL offset line would be drawn at a height of 6.7m (appropriately scaled) above the ground line. Along the footpath it would be drawn at 5.5m.

The GL Offset allows the designer to check that conductors do not sag below the minimum vertical clearance. (An alternative approach is to reduce pole heights by the required vertical ground clearance.)

5. SELECT STRUCTURE & POLE-TOP CONSTRUCTION TYPE

Refer to ‘Pole Selection Guidelines’ and ‘Poletop Constructions’, Selection Guidelines’.

Factors to be considered include: voltage(s) number of circuits requirement for an overhead earth wire subcircuits such as pilot cable or BBCC vegetation and other local conditions magnitude of mechanical loads – depends on span lengths and stringing

tensions required spanning capability.

6. SELECT STRINGING TENSION AND BASIC SPAN LENGTH In general, the number of poles should be kept to a minimum. When span lengths are long, greater conductor stringing tensions must be used so that adequate ground clearance is maintained, or additional pole height is required. However, if the spans are too long, mechanical forces on the structures will be excessive, and there may be inadequate spacing between phase conductors.

SD

VD

HD


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Gaining the balance between these two requirements is the art of optimal line design, as illustrated below:

Lines in rural locations tend to use longer spans, typically over 100m. However, in urban areas, shorter spans tend to be used due to: the requirement to service smaller lots – poles need to be positioned at

points from which services will emanate the requirement to support public lighting the need to keep structures compact and less visually obtrusive the need to keep stays on poles to a minimum use of larger conductor sizes to supply higher load density increased number of circuits, including communications cables.

As a general guide, the table below shows basic span lengths for various standard stringing tables.

Stringing Table Typical Basic Span Length T42 250m T65 200m

T110 150m T220 100m T440 70m T660 50m T880 35m

The span lengths and tensions used will need to suit the pole-top constructions used – refer ‘Poletop Constructions’ Layout Guides. Subcircuits should not be strung tighter than supercircuits.

2:1 Rule

In general, the longest span within a strain section should not be more than double the length of the shortest span. This rule can be relaxed where:

conductors are strung at T440 or slacker, or suspension structures of 11SU, 11SUA or 11SUAH are used.

Nonetheless, no span in the strain section should be longer than double the MES or shorter than half the MES.

7. NOMINATE POLE POSITIONS

In urban areas, poles are generally positioned on the roadway in line with alternate lot boundaries in order to service each property without service lines crossing adjacent properties.

Positioning poles close to gates, driveways, large trees or in a way that obstructs views from houses should be avoided.


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It is often preferable to position the poles on the side of the road with the greatest number of lots so as to keep the number of cross-road services to a minimum.

Public lighting requirements may also influence pole positions. In general, straight lines are preferable to lines with numerous deviation angles, both aesthetically and due to minimising forces on structures. Avoid switching sides of the road more often than is necessary, as phase transpositions on LV lines will be required (if there are two or more successive poles on the opposite side).

Span lengths should be similar within a strain section. Remember the 2:1 rule mentioned on the previous page. All span lengths should be compatible with the stringing tension and pole-top constructions employed (refer ‘PoleTop Constructions’ and ‘Stringing Tables’).

Where practical poles should not be located where they are likely to impede the vision of motorists or where they are likely to be struck by errant vehicles, e.g. on a sharp corner, or the outside radius of a curve. Adequate space should be available for stays fitted to poles. Avoid locations where: access is difficult (eg steep embankments, heavily-vegetated areas, or

down narrow laneways) pole foundations will be poor (eg swampy ground, open drains,

irrigation or flood-prone areas, loose sand) excavation is difficult (eg rocky ridges, bedrock or shale close to

surface, numerous or sensitive underground services).

For a line over undulating ground, avoid placing poles at the bottom of a dip, as uplift will likely occur. Poles are best placed on the shoulders either side of a gully.

Whenever pole positions are altered, you will need to recalculate the MES.

8. NOMINATE STRAIN POINTS, POLE HEIGHTS AND CIRCUIT ATTACHMENT HEIGHTS

Strain points, or shackles are placed in a line at typically every 5th to 10th pole. Factors influencing the placement of shackles include: creating manageable sections of line for construction or repair crews –

strain sections should not be longer than can be erected and tensioned by an average crew in a day.

length of cable on drum – typ. 1200m for bare mains keeping all spans within the strain section of similar length isolating critical spans, eg across a highway, railway, or creek, or spans

that are prone to damage, from the rest of the line providing points for electrical isolation (by breaking bridges, or where

temporary ABSs may be installed by live line crews) accommodating large deviation angles avoiding uplift. For general guidelines on pole sizing, refer ‘Poles’; concrete and wood pole data. The heights nominated for poles will depend upon factors such as: the number of circuits supported the area traversed – clearances vary for road crossings, footpaths, non-

trafficable areas etc mounting heights of public lighting, pole-mounted plant or other

attachments.

For standard king bolt spacing refer ‘Clearances’ and ‘Poletop Constructions’. Increased spacings may be required for long spans, as determined by profiling of the line. Remember that conductor heights may be different from kingbolt heights. On pin constructions, the conductors are above the king bolt; on suspension constructions, they are below. The mimic diagrams in Section 4 ‘Poletop Constructions’ provide dimensions.


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9. DRAW CIRCUIT PROFILE

The conductor profile may be drawn manually by using a boomerang-shaped template, or by plotting points on the catenary curve.

9.1 Supports Poles are drawn to scale on the profile, with marks placed at the support points for each circuit.

The conductor profile is drawn for each circuit, linking the two support points.

9.2 Conductor Temperatures for Profiling Conductor sag depends upon conductor temperature. Various temperatures are used for different purposes, as tabulated to the right. For a standard new HV super circuit + LV subcircuit open-wire line, we would draw profiles for both Winter Night and Summer Day conditions: For HV feeders with an overhead earthwire, intercircuit spacing should be checked with both circuits at 40C. See in Section 5 for required design clearances.

Old Design Ratings. For reference only to determine thermal ratings of exisiting circuits. All new construction is to be designed to the standards on the table to the right. 55”A” Supercct / Subcct 55/15C 75”A” Supercct / Subcct 75/15C 55”B” Supercct / Subcct - Winter night 55/15C, Summer Day 90/35C 75”B” Supercct / Subcct - Winter night 75/15C, Summer Day 110/35C

Check for Uplift

Standard

5C

Western Areas

0C

Check for Clearance to Ground and Fixed Objects

33kV Open Wire 11kV & LV Open Wire

110C 75C

LVABC & 11kV CCT 80C Communications Cables (Pilot, BBCC etc)

55C

HVABC (catenary) 50C

Check for both Winter Night and Summer Day conditions

Winter Night Supercircuit 33kV Open Wire 11kV Open Wire 11kV CCT HVABC (catenary) Winter Night Subcircuit

75C 75C 60C 25C

15C

Summer Day Supercircuit 33kV Open Wire 11kV Open Wire 11kV CCT HVABC (catenary) Summer Day Subcircuit

110C 75C 80C 50C

35C

Cold

Hot

Cool

Hot


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9.3 Drawing a Circuit Profile Using a Sag Template

Although profiling is generally done with computer software nowadays, the approach shown below is one using a sag template and well illustrates design principles. A sag template is made from a transparent material and is designed to overlay the ground line profile already drawn. The template is positioned to link the two support points for the circuit.

The top edge is used for drawing a cold (or cool) condition curve and the bottom edge for the hot condition.

The template is asymmetrical to allow for undulating terrain or dissimilar heights at the ends of the span. Being transparent, it is reversible and may be oriented with the high side to either the left or the right. The template has horizontal and vertical scales that must match those used to draw the ground profile. The datum lines or scales on the template must be aligned with the grid of the graph paper, i.e. tilting the template will produce error. The vertical datum or scale must lie between the two support points. If this is not the case, then an uplift condition may exist.

Be sure that you have selected the correct template, one that: applies to the type of conductor being profiled – different templates

should be used for AAC, Copper, LVABC etc. has the correct stringing table has the correct MES range for the line – ie the strain section MES

should not be significantly below or above the template MES has scales that match the ground profile has the correct hot and cold/cool temperatures.

For constructions in which the phase conductors are at different heights, eg vertical delta, vertical or wishbone, it may be necessary to profile both upper and lower phases within the circuit. Templates may be constructed using the procedure used for plotting a circuit profile, as described in the next sub-section. The plot may be photocopied onto an acetate sheet, which is then cut to produce a template. Be sure to mark/label the template with: type/class of conductor, eg AAC stringing table, eg T220 datum lines scales, eg 1:1000 hor. & 1:200 vert. curve temperatures eg 5C and 75C MES used for calculation, project name, if applicable.

GL

GL Offset


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9.4 Plotting a Circuit Profile The profile of an overhead conductor span is the shape of a catenary. For practical purposes on distribution lines, this shape may be approximated by a parabola. (For sags less than 9% of span length, the difference between the catenary and the parabola is less than 1%.)

The relationship between span and sag is illustrated below.

Where the difference between support point heights is not too great, the circuit profile may be plotted directly onto the ground profile using this technique. However, where significant height difference exists between the ends of the span, a template should be constructed and used as described in subsection 9.3.

10. CHECK VERTICAL CLEARANCES

The profile is checked (refer ‘Clearances’), to ensure that: the circuit profile does not cross below the GL Offset line that adequate clearances are maintained between supercircuits and

sub-circuits all vertical clearances are maintained from structures and other

services.

Where ground clearances are inadequate, the designer may need to consider: increasing pole height, or reducing span lengths, or increasing stringing tension. Where intercircuit clearances are inadequate, the designer may need to: increase king bolt spacing, or alter type of construction, or reduce span lengths, or increase tension in top circuit, or decrease tension in bottom circuit.

25%

75%


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11. CHECK FOR UPLIFT

An upward force may be exerted on a structure under cold conditions when mains are tight. While this may be tolerable for a strain (shackle) construction, it is unacceptable for pin, angle or suspension constructions.

The check for uplift is made by ensuring that the low point of the 5C circuit profile is always between the support structures, as illustrated below.

It is possible to avoid uplift on successive steeply-inclined spans whilst still having the low points outside the spans. However, if the low points are within their respective spans, uplift will never occur.

Uplift problems can also be avoided by: selection of suitable pole positions selective use of increased height poles use of moderate stringing tensions shackling the mains where uplift is unavoidable.

12. CHECK HORIZONTAL CLEARANCES

A check should be made to ensure that there are adequate horizontal clearances between the line and buildings, streetlight columns, embankments, etc, (refer ‘Clearances’).

Also, the designer should ensure that the easement or footpath has sufficient width to avoid the line entering private property under wind conditions. Blowout is essentially horizontal sag in a conductor due to wind forces. It is sometimes greater than sag in a span, since wind forces on the conductor may be greater than gravitational force. Values of blowout for different conductors under various stringing tensions are tabulated in section 7. The blowout at any point along a span may be calculated using the values for a parabola given in subsection 9.4 above.


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A plan view of the circuit may be drawn. At the midpoint of each span, a line equal to the blowout for the span is drawn at right angles to the centreline. A parabola may be then be plotted for the span, as illustrated below.

Where horizontal clearances are inadequate, the designer may need to consider: increasing stringing tension, or altering type of construction, eg vertical instead of flat, or using insulated conductors reducing span lenth relocating poles.

13. CHECK STRUCTURE CAPACITY MATCHES MECHANICAL LOADS

The mechanical forces on each pole should be checked and compared with pole strengths (refer ‘Poles’ and ‘Mechanical Loads’). Special attention should be paid to deviation angle and termination poles. For in-line intermediate poles, it is normally only necessary to check the pole with the greatest wind span.

Where the mechanical load exceeds pole strength the designer should consider: increasing pole strength rating, or backstaying the pole, or reducing stringing tension, or using a concrete pole.

14. NOMINATE FITTINGS AND OTHER REQUIREMENTS

The designer needs to nominate appropriate: shackle (strain point) locations bridging (refer ‘Poletop Constructions’) clamps and connectors (sized to suit conductor and bridging wire sizes,

correct metal to avoid corrosion between dissimilar metals) – Refer Overhead Construction Manual Section 8

sleeves, splices, helical terminations as applicable – Refer Overhead Construction Manual Section 8

insulator types (refer ‘Poletop Constructions’) anti-vibration and vibration protection measures (refer ‘Poletop

Constructions’) lightning protection, as applicable earthing (refer ‘Earthing’) vegetation clearing requirements (refer WCS 1.6).

15. MODIFY DESIGN AS REQUIRED

Frequently it will be necessary to modify the design as it progresses so as to: meet engineering requirements such as clearances, structural

soundness etc to optimise the design, keeping costs to a minimum.

Keeping the number of structures to a minimum is important in minimising costs.

Max. Blowout


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When optimising the design, ‘whole-of-life’ costs should be considered, taking into account: initial cost of materials initial cost of construction the expected life of the components operational costs maintenance costs reliability.

Consult planning staff for assistance to assess any design options equitably.

The design should be practical to construct and maintain. It should make adequate provision for future development (eg fitting of street lights, servicing, addition or uprating of circuit). However, designers should not make excessive provision for developments that are uncertain, many years in the future, or may be paid for at a future time by some other party.

16. DOCUMENT DESIGN

This final stage involves documenting the design as a works plan, complete with schedules. The conductor schedule should make due allowance for inelastic stretch when nominating construction sags. The design should be thoroughly checked using a checklist. All relevant documentation must be placed on the design file for the project. At this stage there will be numerous other tasks to complete, such as: obtaining approvals from stakeholders and relevant authorities establishing easements preparation of resource estimates ordering materials.


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MEASURING SAG ON AN EXISTING CIRCUIT

Using a Height Stick

1. Measure conductor height at each end of the span. 2. Measure conductor height at mid-point of span (not necessarily the point

where the mains are closest to the ground). Do not pull down on the conductor being measured.

3. If the ground is not level or evenly sloping, then take a sight line correction to compensate for any mid-span dip or hump, as described in steps 4 – 6.

4. Place a mark on each pole at eye level, say 1.65m. 5. From one end, sight from one eye line to the other. 6. Have an assistant stand at the midpoint of the span holding the height

stick. Signal to the assistant as to the position of the sight line, and record the height.

7. The sag in the span is given by the formula:

Sag = (h1 + h2) / 2 – hm + ( SL – 1.65 )

Using A Multifunction Laser EDM with Internal Inclinometer

1. Stand at a point from which the entire span can be viewed. 2. Set the instrument to read VD (vertical distance relative to instrument or

eye height). 3. Measure conductor heights (relative to instrument) at supports at each

end of the span. 4. Measure conductor height mid-span (relative to instrument). 5. Calculate sag by subtracting midspan height from the average of the two

support heights:

Sag = (VD1 + VD2) / 2 – VDm

VD1VD2

VDm

Instrument/Eye Height

Sag

h1 h2

hm

SL 1.65 1.65

Sag


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DESIGN EXAMPLE DESIGN INFORMATION A new commercial development at 107 Irvine Rd is to be supplied by a 500kV.A padmounted transformer on the consumer’s property, as shown below. The new transformer is to be fed via an overhead extension emanating from Pole 9973 in Pearl Rd. The project planners have specified that MOON Conductor (7/4.75 AAC) be used for the 11kV extension. A 95mm2 LVABC tie is also to be established between the external network and the new transformer. Irvine Rd slopes downward from west to east, with a bridge across a small non-navigable creek.

The route of the new line has been profiled using a clinometer and trundle wheel, with distances and slopes measured shown below.

The heights of the existing pin crossarms on P9973 are 10.1m (11kV) and 8.3m (LV). The mains heights mid-span, either side of P9973, are 9.3m (11kV) and 7.2m (LV).

The pole alignment in the footpath specified by the local authority is 3.65m from the real property boundary. The soil is hard clay, except in the swampy region in the immediate vicinity of the creek.

Design the new section of overhead line.

Irvine

Creek

Dowling

Pearl

Rd

Rd #103 #105 #107

PROPOSED NEW LOAD

P9974

P6721

P9973

3-7/12(11) 4-mo(L)

50m

50m

50m 0

14m +311m 021m -318m -1

40m -3

P9973 New Pole UG Cable Termination

N


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DESIGN SOLUTION

The total route length is 155m. This is too far to cover with a single span, since LVABC has a practical spanning limit of 100m (refer ‘Poletop Constructions’). Consequently, we will aim to use two spans to cover the distance. As a general rule LVABC is limited to T440. We recognize that the spans will be rather long for T440 stringing, but hope that we can use the terrain in our favour.

We need to select a position for the intermediate pole. The two possible locations are:

in line with the western (upper) lot boundaries of Lot 105, or in line with the eastern (lower) lot boundary of Lot 105.

The top location seems best since:

it is generally good practice to place poles on ridge shoulders and use a longer span over a gully

the level of attachment of the LVABC on existing pole P9973 will be low, so we will need the shorter span on the western side.

Thus, our new extension will appear as shown below in plan view.

Irvine

Creek

Dowling

Pearl

Rd

Rd#103 #105 #107

PROPOSED NEW LOAD

P9974

P6721

P9973

3-7/12(L) 4-mo(11)

50m

50m

50m 0

14m +311m 0 21m -3 18m -1

40m -3

P9973New Pole UG Cable Termination

N

New Intermediate Pole

1

2 3

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At station 1, ie P9973, we will need to fit terminations for the new circuits, viz 11T and LVABC/T. In order to meet the required spacings between circuits (refer ‘Clearances’) the existing LV crossarm on P9973 will require lowering. The spacings will change as shown below. The lowering of the LV crossarm by 1.05m does not present any problems for the line in Pearl Rd. The mid-span height of the LV mains will be reduced from 7.2m to (8.3-1.05/2) = 6.675m. Note as the height is modified 1.05m at one end, only ½ of 1.05m will be achieved mid-span. The resulting mid-span height of 6.675m exceeds minimum height requirement of 5.5m. (Refer ‘Clearances’). Note that In this example KingBolt spacings have been used for profiling while in practice actual conductor heights shall be used (variations result from type of construction used refer Overhead Construction Manual).

A ground line profile is now required. Using trigonometry, we convert the measured distances and slope angles to chainage and level values, as tabulated below.

Description Distance Slope HD VD Chainage Level Stn 1 P9973 0 0 51 0 51 0 51 0 40 -3 40 -2.09 91 -2.09 18 -1 18 -0.31 109 -2.40 21 -3 21 -1.10 130 -3.50 Creek 11 0 11 0 141 -3.50 Stn 3 14 +3 25 + 0.73 155 -2.77

These may be used to plot a profile with a horizontal scale of 1:1000 and a vertical scale of 1:200, as shown below.

We will draw a minimum ground clearance line parallel with the ground line. For the most part, this line shall be 5.5m above the ground line. However, near the creek where the ground is not trafficable we may reduce the clearance to 4.5m.

EXISTING PROPOSEDP9973

11P

LVP 8.30

10.10

LVP 7.25

10.1011P

11T

LVABC/

9.45

6.95

)0.65

)0.3

)2.2 1.05


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We shall now add the poles to the profile. We already have measured heights for station 1. Initially, we will select a 12.5/8-14L pole for station 2. The pole at station 3 will need to be taller, and heavier since it is a termination pole with 11kV and LV underground cables terminating on it, say 14/12-22L. (Incidentally, we may need to revise these heights later if there is insufficient clearance.) We now refer to ‘Poles’ and select suitable pole foundations and sinking depths. The soil is well-drained hard clay and provides a good foundation. Our selections are as follows: Stn 2 Sink 2.05m NAEF (natural earth fill foundation) Stn 3 Sink 2.30m NAEF (natural earth fill foundation) The heights of the poles out of ground shall be: Stn 2 10.45m Stn 3 11.70m.

We now need to nominate constructions and calculate the heights of circuit attachment points on the poles at stations 2 and 3.

The mains may be run in a single strain section, since the two spans are not greatly dissimilar in length (cf 2:1 guideline). The MES in the new strain section is calculated as follows: MES = ((903 + 653) / (90 + 65) = 80.5m (Refer ‘Stringing Tables’) By reference to ‘Clearances’, we obtain the values tabulated below.

Station Construction KBS King Bolt Height Conductor Height 2 11TDA 0.15 10.30 10.30 (A, C ph)

LVABC/SU3 1.60 8.70 8.50 3 11T 0.15 11.55 11.55

11 UG Term. 1.40 10.15 LVABC/T 1.80 8.35 8.35

LV UG Term. 0.15 8.20 We also verify that the distances and angles are within the capability of the nominated constructions by reference to layout guides in ‘Poletop Constructions’. (Note that the line deviation angle at station 2 is 4.) We will need to plot the circuits for the following conditions:

11kV 75C Intercircuit clearance LV 15C Intercircuit clearance LV 80C Ground clearance-Hot condition for LVABC

Uplift is not a concern in this instance and there is no need to plot profiles at 5C.


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To plot the circuits, we will either need to: obtain a suitable sag template, or determine the sag in each span by reference to sag tables.

Assuming that we take the latter course, we are able to calculate sags as tabulated below (refer ‘Stringing Tables’).

Circuit Stringing Temperature Sag 1 – 2

(65m span) Sag 2 – 3

(90m span) 11kV T440 75C 2.21m 4.24m LV T440 15C 1.86m 3.56m LV T440 80C 2.23m 4.29m

We are now able to draw our profile, as shown below.

Notice that the 80C catenary curve for the LVABC falls below the ground

line offset clearance line. Our design is therefore unsatisfactory.

We have two options here:

Increase pole height at station 2, or Increase stringing tension.

We will select the first option, as T220 is only to be used on LVABC if

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We now check horizontal clearances and blowout. We need only consider the longer span. By reference to ‘Stringing Tables’ we find blowout to be as follows: 11kV MOON T220 2.01m + 0.6m trident constr. width from centre LVABC95 T440 3.18m + 0.2m half pole width We note that even with allowances for pole/construction width, the blowout is satisfactory, ie less than the 3.65m that the pole is away from the real property boundary, although there is not a lot of margin. In this case, the design is acceptable, since there are no buildings or structures in proximity to the middle of the 90m span. We now check the tip loads on the poles, with results as shown below. (Refer to section 2.11 for information on tip load calculation)

Station No Wind Wind

1 6.00kN 22.33kN 2 0.46kN 6.37kN 3 6.14kN 22.77kN

We now compare these loads with the pole strengths given in section 2.3. At station 1, the ‘Wind’ condition tip load exceeds that of the pole and staying is required. Station 2 is not overloaded. At station 3, we can manage the load if we use a 14/20-36L pole. Since ground space is limited at station 1 by the property boundary, we will opt for a sidewalk type stay. Reference to ‘Stays’ section 3.3 indicates that with a 5 angle on the stay wire relative to vertical the stay will have a strength of 31.5kN, well above the 22.3kN load. The stay anchor will be installed 3050mm from the pole, which will be 600mm from the RP boundary, which is sufficient.

Screw anchor will be (refer ‘Stays’): Station 1 - single screw 200mm blade diameter, installed @ 140 bar

Since we are able to interconnect to the external LV network, and we do not anticipate any problems with earthing, we shall specify CMEN earthing for the cable termination. A common cable guard may be used for the HV and LV cables, affixed to the eastern side of the pole at station 3 opposite the direction of oncoming traffic. (The HV cable will twist around the pole for the termination on the west side.) We will also need to specify bridging between the existing line and the new line at station 1. Referring to the Overhead Construction Manual page section 8, page 33 & 34, we specify the following bridging arrangements: 11kV: 6m x 20279 CCT, 6 x 5893 clamps LV: 4 x 14090 clamps

Note in both cases the mains are extended to act as bridging cables. This is a preferred practice that minimises the number of joints (which is a good thing for increased network reliability).

We are now ready to document the design as a works plan.


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© COPYRIGHT 2015 Energex This drawing must not be reproduced in part or whole without written permission from ENERGEX

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Note 1: Allowable pole tip load under Limit State & Maximum Working Wind Conditions Note 2: Data taken from Technical Specification TS415C – Vacuum – Pressure Impregnated Hardwood Poles

13 9 5 195 135 210 145 220 15520 14 8 230 165 245 175 260 190 360 360 38030 22 12 265 195 280 210 295 22050 36 20 N/A N/A 350 250 N/A N/A 515 515 53513 9 5 210 135 225 150 240 16020 14 8 250 170 265 185 280 19530 22 12 285 200 300 215 320 23013 9 5 225 135 240 150 255 16020 14 8 265 170 280 185 295 19530 22 12 300 200 320 220 335 23013 9 5 235 140 250 150 265 16020 14 8 275 170 295 185 310 19530 22 12 315 200 335 215 355 23513 9 5 250 145 265 165 280 16520 14 8 290 170 305 185 325 20030 22 12 330 205 350 215 370 23550 36 20 395 260 420 285 445 31013 9 5 260 155 275 165 290 17520 14 8 300 180 320 195 335 20530 22 12 345 210 365 230 385 24550 36 20 410 255 435 285 455 30013 9 5 265 160 285 170 300 18020 14 8 310 190 330 200 350 21530 22 12 355 220 380 235 400 25050 36 20 420 265 450 285 475 30513 9 5 275 165 290 175 310 18520 14 8 320 195 340 210 360 22030 22 12 370 225 390 240 410 25550 36 20 435 270 465 290 490 31013 9 5 285 170 300 180 320 19020 14 8 330 200 350 215 370 22530 22 12 380 230 400 250 425 26550 36 20 450 280 475 295 505 31513 9 5 290 175 310 185 325 19520 14 8 340 205 360 220 380 23530 22 12 390 240 415 255 435 27050 36 20 460 285 490 305 515 32513 9 5 300 180 315 190 335 20020 14 8 350 210 370 225 390 24030 22 12 400 245 425 260 445 27550 36 20 470 295 500 310 530 330

20 2600

21.5 2750

23 2900

15.5 2150

17 2300

18.5 2450

600 600 630

Length (m)

(Note 1) S1 S2 S3

575 575 605

590 590 615

540 540 565

555 555 580

500 500 520

515 515 535

380 380 395

400 405 425

2m from butt

2m from butt

360 360 380

2m from butt

At head

At head At head

POLE DESCRIPTION MINIMUM POLE DIAMETERS (mm) MAX. DIAMETER at GLNominal GL

Distance from Butt

(mm)

Strength Rating (kN) Strength Group Strength Group Strength Group

S1 S2 S3

Limit State Max. Working

8 1400

Ultimate

9.5

11

12.5

14 2000

1850

1700

1550


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TIP LOAD CAPACITY OF NAILED POLES – WIND CONDITION (kN) Rebutted Poles can be assumed to be reinstated to their full original strength. Nailed or Staked Poles are often reinstated to less than their original strength, but adequate to carry the applied tip load at the time of reinstatement. Nails are currently stamped with the Ultimate Bending Moment Capacity of the pole and the year of installation. (Older nails may not be stamped in this way – refer section 2.7. Use the tables below to determine Tip Load Capacity of the reinstated pole. Note: Even if the nail is of a large capacity, the tip load of the reinstated pole must NOT exceed the original tip load of the pole.

Poles where the Nail is Aligned with the Resultant Conductor Load

ULTIMATE BENDING MOMENT CAPACITY OF NAIL (kN.m) POLE LENGTH (m) 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220

8 4.63 6.03 7.44 8.85 10.25 11.66 13.06 14.47 15.88 17.28 18.69 20.10 21.50 22.91 24.31 25.72 27.13 28.53 29.94 9.5 3.21 4.37 5.53 6.69 7.85 9.02 10.18 11.34 12.50 13.66 14.82 15.98 17.14 18.31 19.47 20.63 21.79 22.95 24.11 11 2.00 2.99 3.98 4.97 5.96 6.95 7.94 8.93 9.92 10.91 11.89 12.88 13.87 14.86 15.85 16.84 17.83 18.82 19.81

12.5 0.90 1.76 2.62 3.48 4.34 5.20 6.07 6.93 7.79 8.65 9.51 10.37 11.23 12.09 12.96 13.82 14.68 15.54 16.40 14 0.59 1.35 2.12 2.88 3.64 4.41 5.17 5.93 6.69 7.46 8.22 8.98 9.74 10.51 11.27 12.03 12.80 13.56

15.5 0.13 0.82 1.50 2.19 2.87 3.55 4.24 4.92 5.61 6.29 6.98 7.66 8.34 9.03 9.71 10.40 11.08 17 0.16 0.78 1.40 2.02 2.64 3.26 3.88 4.50 5.12 5.74 6.37 6.99 7.61 8.23 8.85

18.5 0.53 1.10 1.66 2.23 2.80 3.37 3.94 4.50 5.07 5.64 6.21 6.77 20 0.09 0.62 1.14 1.66 2.19 2.71 3.23 3.76 4.28 4.80

The above table assumes a ground line pole diameter equivalent to 3% of pole length. Sinking Depth is taken to be 0.1 x Pole Length + 0.8m.

Resultant

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Maximum Tip Load – Wind Condition (kN)


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Poles where the Nail is NOT Aligned with the Resultant Conductor Loads

The above table assumes a ground line pole diameter equivalent to 3% of pole length. Sinking Depth is taken to be 0.1 x Pole Length + 0.8m.

ULTIMATE BENDING MOMENT CAPACITY OF NAIL (kN.m) POLE LENGTH (m) 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 200 210 220

8 2.75 3.69 4.63 5.56 6.50 7.44 8.38 9.31 10.25 11.19 12.13 13.06 14.00 14.94 15.88 16.81 17.75 18.69 19.63 9.5 1.66 2.44 3.21 3.98 4.76 5.53 6.31 7.08 7.85 8.63 9.40 10.18 10.95 11.73 12.50 13.27 14.05 14.82 15.60 11 0.69 1.34 2.00 2.66 3.32 3.98 4.64 5.30 5.96 6.62 7.28 7.94 8.60 9.26 9.92 10.58 11.23 11.89 12.55

12.5 0.32 0.90 1.47 2.05 2.62 3.19 3.77 4.34 4.92 5.49 6.07 6.64 7.21 7.79 8.36 8.94 9.51 10.08 14 0.34 0.85 1.35 1.86 2.37 2.88 3.39 3.90 4.41 4.91 5.42 5.93 6.44 6.95 7.46 7.97

15.5 0.13 0.59 1.04 1.50 1.96 2.41 2.87 3.33 3.78 4.24 4.69 5.15 5.61 6.06 17 0.16 0.57 0.99 1.40 1.81 2.23 2.64 3.06 3.47 3.88 4.30

18.5 0.34 0.72 1.10 1.47 1.85 2.23 2.61 20 0.27 0.62 0.97

Resultant Nail

Maximum Tip Load – Wind Condition (kN)


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BENDING MOMENT CAPACITY OF WOOD POLES

NOTES: 1. All Bending Moment values are in kN.m.

2. Dia (mm) is typically ground line diameter but may be applied to any part of the pole. 3. The following Modulus of Rupture values have been used in accordance with

AS3818.11. S1: 100Pa, S2: 80MPa, S3: 65MPa. 4. To convert from Bending Moment to Tip Load Capacity in kilo-Newtons, divide by

height in metres. For wind condition, de-rate by self-windage of pole: i.e. height (m) x width (m) x 1.3 x 0.5. 5. To obtain Energex allowable “No Wind” bending moments, multiply the “No Wind”

value by 0.57. Refer section 2-12 for more information.

Diameter (mm)

S1 S2 S3 Ult

(kN.m) No

Wind(5) (kN.m)

Wind (kN.m)

Ult (kN.m)

No Wind(5) (kN.m)

Wind (kN.m)

Ult (kN.m)

No Wind(5) (kN.m)

Wind (kN.m)

120 16.96 6.79 12.21 13.57 5.43 9.77 11.03 4.41 7.94

130 21.57 8.63 15.53 17.26 6.90 12.42 14.02 5.61 10.09

140 26.94 10.78 19.40 21.55 8.62 15.52 17.51 7.00 12.61

150 33.13 13.25 23.86 26.51 10.60 19.09 21.54 8.61 15.51

160 40.21 16.08 28.95 32.17 12.87 23.16 26.14 10.46 18.82

170 48.23 19.29 34.73 38.59 15.34 27.78 31.35 12.54 22.57

180 57.26 22.90 41.22 45.80 18.32 32.98 37.22 14.89 26.80

190 67.34 26.94 48.48 53.87 21.55 38.79 43.77 17.51 31.51

200 78.54 31.42 56.55 62.83 25.13 45.24 51.05 20.42 36.76

210 90.92 36.37 65.46 72.74 29.09 52.37 59.10 23.64 42.55

220 104.54 41.81 75.27 83.63 33.45 60.21 67.95 27.18 48.92

230 119.45 47.78 86.00 95.56 39.22 68.80 77.64 31.06 55.90

240 135.72 54.29 97.72 108.57 43.43 78.17 88.22 35.29 63.52

250 153.40 61.36 110.45 122.72 49.09 88.36 99.71 39.88 71.79

260 172.55 69.02 124.24 138.04 55.22 99.39 112.16 44.86 80.75

270 193.24 77.29 139.13 154.59 61.84 111.30 125.60 50.24 90.44

280 215.51 86.21 155.17 172.41 68.96 124.14 140.08 56.03 100.86

290 239.44 95.78 172.40 191.55 76.62 137.92 155.63 62.25 112.06

300 265.07 106.03 190.85 212.06 84.82 152.68 172.30 68.92 124.05

310 292.47 116.99 210.58 233.98 93.59 168.46 190.11 76.04 136.88

320 321.70 128.68 231.62 257.36 102.94 185.30 209.10 83.64 150.56

330 352.81 141.12 254.02 282.25 112.90 203.22 229.33 91.73 165.12

340 385.87 154.35 277.82 308.69 123.48 222.26 250.81 100.33 180.59

350 420.92 168.37 303.07 336.74 134.70 242.45 273.60 109.44 196.99

360 458.04 183.22 329.79 366.44 146.57 263.83 297.73 119.09 214.36


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NOTES: 1. All Bending Moment values are in kN.m.

2. Dia (mm) is typically ground line diameter but may be applied to any part of the pole. 3. The following Modulus of Rupture values have been used in accordance with AS3818.11. S1: 100Pa, S2: 80MPa, S3: 65MPa. 4. To convert from Bending Moment to Tip Load Capacity in kilo-Newtons, divide by height in

metres. For wind condition, de-rate by self-windage of pole: i.e. height (m) x width (m) x 1.3 x 0.5. 5. To obtain Energex allowable “No Wind” bending moments, multiply the “No Wind” value by

0.57. Refer section 2-12 for more information.

Diameter (mm)

S1 S2 S3 Ult

(kN.m) No

Wind(5) (kN.m)

Wind (kN.m) Ult (kN.m)

No Wind(5) (kN.m)

Wind (kN.m)

Ult (kN.m)

No Wind(5) (kN.m)

Wind (kN.m)

370 497.28 198.91 358.04 397.83 159.13 286.44 323.23 129.29 232.73

380 538.70 215.48 387.87 430.96 172.39 310.29 350.16 140.06 252.11

390 582.36 232.94 419.30 465.89 186.36 335.44 378.54 151.41 272.55

400 628.32 251.33 452.39 502.65 201.06 361.91 408.41 163.36 294.05

410 676.63 270.65 487.17 541.30 216.52 389.74 439.81 175.92 316.66

420 727.36 290.94 523.70 581.889 232.75 418.96 472.78 189.11 340.40

430 780.56 312.22 562.00 624.45 249.78 449.60 507.36 202.94 365.30

440 836.29 334.52 602.13 669.03 267.61 481.70 543.59 217.44 391.38

450 894.62 357.85 644.12 715.69 286.28 515.30 581.50 232.60 418.68

460 955.59 382.24 688.03 764.47 305.79 550.42 621.14 248.45 447.22

470 1019.28 407.71 733.88 815.42 326.17 587.10 662.53 265.01 477.02

480 1085.73 434.29 781.73 868.59 347.43 625.38 705.73 282.29 508.12

490 1155.02 462.01 831.61 924.01 369.60 665.29 750.76 300.30 540.55

500 1227.18 490.87 883.57 981.75 392.70 706.86 797.67 319.07 574.32

510 1302.30 520.92 937.65 1041.84 416.74 750.12 846.49 338.60 609.48

520 1380.41 552.17 993.90 1104.33 441.73 795.12 897.27 358.91 646.03

530 1461.60 584.64 1052.35 1169.28 467.71 841.88 950.04 380.01 684.03

540 1545.90 618.36 1113.05 1236.72 494.69 890.44 1004.83 401.93 723.48

550 1633.38 653.35 1176.03 1306.71 522.68 940.83 1061.70 424.68 764.42

560 1724.10 689.64 1241.36 1379.28 551.71 993.08 1120.67 448.27 806.88

570 1818.13 727.25 1309.05 1454.50 581.80 1047.24 1181.78 472.71 850.88

580 1915.51 766.20 1379.16 1532.40 612.96 1103.33 1245.08 498.03 896.46

590 2016.30 806.52 1451.74 1613.04 645.22 1161.39 1310.60 524.24 943.63

600 2120.57 848.23 1526.81 1696.46 678.58 1221.45 1378.37 551.35 992.43


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1. POLE INSPECTION FOR IN-SERVICE POLES

Whenever the tip load of an in-service pole is increased by more than 1kN (No Wind condition), an assessment of the residual strength of the pole is required. Poles that are less than 10 years old, or that have been reinstated (ie nailed or rebutted) within the last 10 years, shall be exempt from this procedure. The designer shall complete Section 1 of Form 1271 “Pole Inspection for Altered Tip Loads” supplying the pole site ID and address. This should be forwarded to the Network Maintenance Contract Department. The Contract Officer shall arrange for a pole inspector under the current contract to inspect the pole and obtain the necessary field measurements for wood poles – ground line diameter, height and dimensions of any internal hollows – completing Section 2 of the form. The form is returned to the designer. For wood poles, the designer should then calculate a revised pole tip load rating using the measurements provided and the PoleStrength program within the mains design application package. Only the Limit State (LST) and Everyday (EDT) values are to be used to determine the remaining design strength of the pole. This strength is to be compared with the proposed LST tip load to determine the suitability of the existing pole.

External designers have the option of liaising directly with a rated Pole Inspector to obtain the required measurements. For wood poles without any internal hollows, the table in Section 2.8 Bending Moment Capacity Of Timber Poles may be used in lieu of the PoleStrength program. Ensure any external decay is taken into account when determining diameter of pole

For reinstated poles that are assessed as sound by the pole inspector, the designer shall compare the strength of the reinforcing system with the proposed tip load (refer Page 2-6 and Maintenance Instruction MI-069).

2. POLE PEGGING Poles and stays shall be pegged at the centre of the proposed position. Only ORANGE fluorescent paint (Stock Code 14010) will be used for temporary marking of pole and stay positions and pegs. Refer AS 1345 for temporary marking of electrical services in road reserves Check for services clashes – DBYD (phone 1100, fax 1300 652077).

3. POLE ALIGNMENTS Poles located within road reserves shall be installed on an alignment approved by the authority controlling the roadway – generally the Department of Transport and Main roads or the local authority (council). Standard pole alignments for authorities within the ENERGEX franchise area are tabulated below. Note that certain authorities reference the alignment to the real property boundary, others behind the face of the kerb (BFK) or behind the kerb invert (BKI). Note that local authorities may have additional restrictions on pole placement, eg clearances from walking paths and bike paths.

Restrictions concerning streetlight pole placement are also found in AS/NZS1158 - Road Lighting. As a general guideline, ensure that there is at least 0.7m between the outside of the pole and the kerb to minimise damage from vehicle


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4. STANDARD POLE AND UNDERGROUND ALIGNMENTS

LOCAL AUTHORITY POLE ALIGNMENT U/G ALIGNMENT SITUATION DRAWING REF. COMMENTS NORTH

SUNSHINE COAST REGIONAL COUNCIL Formerly:

Caloundra City Council 3.0m centre from RP Align

0-0.9m from RP Align

(with Gas) For all footpath widths

SEQ STD Electrical

conditions 090824.pdf

Formerly:

Maroochydore City Council 3.0m centre from RP Align 0-0.9m from RP Align For all footpath widths

Formerly:

Noosa Shire Council 3.0m centre from RP Align 0-0.9m from RP Align For all footpath widths

GYMPIE REGIONAL COUNCIL

Formerly:

Cooloola Shire Council 3.0m centre from RP Align

0.3-0.9m from RP

Align R-08

Council considering pole

alignment 1.0m behind

kerb for footpaths

exceeding 4.0m wide

MORETON BAY REGIONAL COUNCIL Formerly:

Caboolture Shire Council 3.2m centre from RP Align

0-1.0m from RP Align

(with Gas) A4/01-64

Formerly:

Redcliffe City Council 3.3m centre from RP Align 0-0.9m from RP Align

For standard footpath 4.0m

wide S19A

Formerly:

Pine Rivers Shire Council

3.05m centre from RP Align 0-0.9m from RP Align For footpaths 3.5m wide 8-0049

0.45m from face of kerb 0-0.9m from RP Align For footpaths exceeding

3.5m wide 8-0049

2.75m centre from RP Align For footpaths without

kerbing Unnumbered sketch


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