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Copyright July 2013 CTC Global Corporation All Rights Reserved 1

CCPTMcan help make the right choice

The CCP software tool can make a difference to system planners and project

engineers , making it easy to compare conductors being considered for any project

Customized to conditions for the specific project requirements

Allows comparison of most conductor types, not just ACCC versus ACSR

Illustrates both performance and economic impact of conductor selection

Compatible with results from PLS CADDTMand Sag 10

Easy to use and supported by CTC Global for any

project planning

When the program is first installed, a CTC icon

will appear on your desktop Program runs in Excel 2007/2010/2013, Windows only

Can contact [email protected]

technical assistance
mailto:[email protected]:[email protected]

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Review of CCP

CCP is downloaded from DropBox after invitation from CTC Global.

The COMPARISONS tab is the functional program.

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CCP: Project Questionnaire

All of the information

needed for an initialconductor comparison is

captured in the Project

Questionnaire.

Everything in yellow are

required fields to fill out Allows CTC Global to get a

good assessment of the

project and more quickly

come to a recommendation

of an ACCC option for the

project

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CCP: Overview of CCP tab

The CCP has a high level

overview of the sections ofdata entry as a reference

for new users.

Gives a brief overview of

the program and its

purposes

This instruction manual

provides more detail of

terms and the impact the

selections will have on the

calculated results

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Input Company and/or Project Name

Conductor Information Base Conductor Conductor #1 Conductor #2 Version Language Voltage Type Select Units

Type: ACCC ACSR ACSS/TW/HS-285 2.5.2 Beta English AC US Units

Size (kcmil Al - Code Word): 1026 - DRAKE 795 - DRAKE 960 - SUWANNEE Environmental Inputs 1

Aluminum Area (kcmil): 1025.6 795.0 959.6 95.9 Sun Radiation (W/ft)

Diameter (in.): 1.108 1.108 1.108 25 Ambient Temp. (C)

Rated Strength (lbf): 41,200 31,500 38,600 2.00 Wind (ft/sec)

Weight (lb/kft): 1,051.8 1,094.0 1,316.5 0 Elevation (ft)

DC Resistance at 20C (ohms/kft): 0.01634 0.02138 0.01720 0.5 Solar Absorptivity

AC Resistance at 25C (ohms/kft): 0.01689 0.02208 0.01782 0.5 Emissivity

AC Resistance at 75C (ohms/kft): 0.02017 0.02633 0.02134 90 Wind Angle (deg.)

0

Conductors per phase: 1 1 1 32 Latitude (neg = South)

Circuits: 1 1 1 June Month

Ampacity (A) at Temperature (C): 70 978 65 800 175 1,708 21 Day of Month

Ampacity (A) at Rated Operating Temp (C): 180 1,786 75 908 200 1,828 12 Time (24 hrs.)

Ampacity (A) at Maximum Temp (C): 200 1,884 100 1,120 250 2,043 Clear Atmosphere

Line Loss (Based on Inputted Peaking Operating Amps Value) Load and Generation Cost Assumptions

Steady-State Temperature (C) at Peak Ampacity: 65 75 67 3.9 Line Length (miles)

Resistance at Peak Operating Amps (ohm/mile): 0.10290 0.13901 0.10955 88 Voltage (kV)

First Year Line Losses (MWh): 4,489 6,065 4,779 908 Peak Operating Amps

ACCC 1026 - DRAKE - Reduces First Year COGenerated by (MT): 929 171 70% Load Factor

ACCC 1026 - DRAKE - Reduces First Year Line Losses by (MWh): 1,576 290 52% Loss Factor

ACCC 1026 - DRAKE - Reduces First Year Line Losses by (%): 26% 6% 138 Peak Power per Circuit (MW)

ACCC 1026 - DRAKE - Reduces First Year Line Losses by ($/Year): 157,566 29,014 3 Phases/Circuit

ACCC 1026 - DRAKE - Line Loss Savings per ft of Conductor ($/ft): 2.58 0.47 100 Cost of Energy Generation ($/MWh)

1.300 CO(lb/kWh)

ACCC 1026 - DRAKE - Reduces 30 year line loss by ($): 4,726,976 870,426 0% Load Increase/Year

ACCC 1026 - DRAKE - Reduces 30 year COgeneration by (MT): 27,874 5,133

Revenue Attainable during Peak Capacity (Limited by Max Sag) Resistance at Peak Capacity (ohm/mile) 4592.69368. . . ea a ac ( )

Peak Power Available for Delivery (20 hrs.) (MWh): 5,621 3,370 4,202 20 Hours/Year at Peak Capacity (hr.)

Potential Revenue for Power Delivered ($): 4,496,963 2,696,285 3,361,731 800 Price of Energy at Peak Capacity ($/MW h)

Initial Sag and Tension: Initial Sag and Tension:

% RTS: 15.0% 20.0% 20.0% 1148.29396 Ruling Span (ft)

Sag at Initial Sagging Temperature (ft): 28.10 28.60 28.10 21 Initial Sagging Temperature (C)

Initial Tension at Sagging Temperature (lbf): 6,180.0 6,300.0 7,720.0 39.4 Maximum Allowable Sag (ft)

Sag/Tension at Above Stringing Temperature: Sag Comparison Graph

Temp(C): 65 75 67

Sag (ft): 33.50 35.30 33.90

Tension (lbf): 5,180.0 5,115.0 6,404.0

Temp(C): 180 75 200

Sag (ft): 35.10 35.30 43.80

Tension (lbf): 4,938.0 5,115.0 4,953.0

Temp(C): 200 100 250

Sag (ft): 35.20 38.10 46.50

Tension (lbf): 4,920.0 4,736.0 4,667.0

Max. Temp(C): 200 100 121

Temperature at Maximum Allowable Sag Sag (ft): 35.20 38.10 39.40

Tension (lbf): 4,920.0 4,736.0 5,510

Ampacity (A): 1,884 1,120 1,398

Wind / Ice or Cold Temperature Sag/Tension: Wind / Ice Conditions

Sag (ft): 26.90 26.20 26.20 0 Temperature (C) Sag (ft):

Tension (lbf): 6,459.0 6,876.0 8,287.0 12.0 Windspeed (mph)

0.00 NESC K-Factor (lb/ft)

Knee Point Temperature Sag/Tension: 0.00 Radial Ice Thickness (in.)

Knee Point Temperature (C): 74 114 109 0.0 Ice Density (lb/ft)Sag (ft): 34.40 39.50 38.70

Tension (lbf): 5038.0 4561.0 5608.0

Ampacity Cells Turn Red if Max Capacity is not reached

Sag at Maximum Temperature

Input Company and/or Project Name

Sag at Peak Operating Amps

Sag at Rated Operating Temperature

Azimuth of Line (NS=0, EW=90)

0

5

10

15

2025

30

35

40

45

50

0 50 100 150 200 250

Sag

(ft):

Temperature (C)

ACCC-1026 -DRAKE

ACSR-795 -DRAKE

ACSS/TW/HS-285-960- SUWANNEE

Maximum AllowableSag (ft)

SetDefault

EnvironmentalInputs

Reviewing steps in making a Comparison

1. Demonstrate the

areas for inputs,

conductor selectionand outputs.

1. Environmental Inputs

2. Line factors/Cost

factors

3. Conductor Selection

4. Ice/wind conditions

5. Sag calculation factors6. Temperature and line

loses

7. Sag and tension

results

8. Visual sag and limits

9. Efficiency and

emissions

10. Thermal Knee Point

calculations

2. All yellow cells are

inputs, can enter

own value or

choose from

dropdown list

1

2

5

6

78

4

9

3

10

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Step 1: Adjusting environmental conditions

CCP is adjustable to Metric or US units for AC

and DC Transmission lines.

Can select language, presently includes English , Chinese,Russian, Vietnamese , Czech, Polish and Spanish

,Sun Radiation (W/m3): IEEE 738 calculates the affect of

the sun radiation on heating the conductor. Is determined

by:

Latitude (neg = South): Determines sun location in

sky

Month: Enter desired month

Day of Month: Enter desired day

Time (24 hrs.): Enter desired time

Atmosphere: Condition of sky

Elevation (m): Determines the atmospheric impact

on the amount of sun radiation on the conductor

Ambient Temp. (C): This sets the base temperature for

performing the ampacity and conductor temperature

calculations. In countries with high seasonal variance, it

can be important to consider summer and winter

conditions separately.

Wind (m/sec): Used to determine the amount of cooling

at the surface of the conductor.

Solar Absorptivity: This factor is used to calculate the

percentage of solar radiation absorbed by the

conductor and converted to heat

Emissivity: This factor is used to calculate the amount

of heat shed by the conductor surface

Wind Angle (deg.): Modifies the effect of wind cooling

Azimuth of Line (NS=0, EW=90): Effects the solar

radiation impact based on the average compass angle

of the line

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7/20Copyright July 2013 CTC Global Corporation All Rights Reserved 7

Step 1: Typical range and impact of changes

These inputs effect the basic capacity rating of

the line, and assumptions made during planning

can result in significant changes in the rating

Sun Radiation (W/m3): The higher the sun radiation value,

the higher the starting temperature of the conductor, and

hence the lower the available capacity of the line

Ambient Temp. (C): The higher the assumed ambient

temperature, the lower the available capacity of the line.

Most calculations are based on temperature at time of peakloading. A 1 C change in temperature results in ~1 to 2%

change in ampacity.

Wind (m/sec): The cooling effect based on wind speed can

have a significant impact on the ampacity rating. A 10%

change in wind speed can have a 5% affect on the ampacity

rating.

Elevation (m): Higher the elevation, the higher the sunradiation amount. Up to 30% more radiation at 4500

meters (15,000 ft) vs. sea level.

Solar Absorptivity: 0.5 is generally assumed for a matte

finished conductor, which will age to 0.9 over time. A 0.9

value results in a ~10% reduction in line ampacity.

However, this is offset by emissivity.

Emissivity: 0.5 is generally assumed for a matte

finished conductor, which will age to 0.9 over time. A

0.9 value results in a 10% increase in line ampacity.

However, this is offset by solar absorptivity.

Wind Angle (deg.): The cooling effect of a 5 angle

change is about 1% change in ampacity. A complete

90 change results in ~30% change in ampacity.

Azimuth of Line (NS=0, EW=90): Depending on the

latitude, the value of the azimuth of the line will

have a small impact on ampacity.

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Step 2: Voltage/CO2/Cost Assumption Inputs

These entries are used as the basis for calculating

operating conditions and economic impact

Line Length (km): Line length is primarily used to determine

the amount of line losses for a project.

Voltage (kV): Impacts only the power delivered by the line.

Presently no power factor is considered.

Peak Op. Amps: The expected maximum amps to be

delivered.

Load Factor: Represents a percentage of peak annual ampsused to calculate the average amps demanded on a daily

basis.

Loss Factor: Is calculated based on load factor by a standard

electrical engineering formula assuming cyclical demand

distribution.

Peak Power per Circuit (MW): Calculated based on standard

formulas for DC and AC power delivery

Phases/Circuit: Based on AC or DC line configuration

Cost of Energy Generation ($/MWh): Based on an

assumption for the weighted average cost of generation.

CO2(kg/kWh): Assumed average CO2generated for each

kWh.

Load Increase/Year: Expected increase load due to demand.

CCP also considers peak loading performance

and economics:

Hours/Year at Peak Capacity (hr.): Hoursexpected to operate during the year at

peak amps

Price of Energy at Peak Capacity ($/MWh):

Selling price per MWh at peak operating

capacity

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Step 2: Typical range and impact of changes

These values affect the economics of the planned

transmission line project:

Line Length (km): The longer the line, the greater the line losses.Any percentage increase in line length is directly proportional to

line losses, assuming constant ampacity across the entire line

length.

(This version of CCP does not calculate voltage drop, SIL, or

other loss factors that can occur along the line)

Voltage (kV): Impacts the peak power of the circuit.

Peak Op. Amps (A): This impacts the calculated resistance of theline. This is a non-linear relationship between resistance and

ampacity. A 10% change in peak operating amps results in a 10%

change in temperature and a 20% change in line losses.

Load Factor: Shifts the minimum and average load distribution.

A 10% change in Load Factor results in a 20% change in line

losses.

Loss Factor: Relates the peak operating amps to the daily

fluctuations in the load and is used in calculating line losses.

Peak Power per Circuit (MW): A calculated circuit load.

Phases/Circuit: Calculated based on voltage type.

Cost of Energy Generation ($/MWh): Basis for economics.

CO2(kg/kWh): Basis for greenhouse gas calculations.

Load Increase/Year: Basis for 30 year calculations.

The revenue achievable during peak operating

conditions is a direct function of these two

inputs. But, this value is also related to themaximum sag condition set for the conductor.

See section 5.

Hours/Year at Peak Capacity (hr.)

Price of Energy at Peak Capacity ($/MWh)

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Step 3: Selection of Conductors and Amps Calculations

All conductor information is

derived directly from the

manufactures conductorspecification and wire files.

Type: Choose from dropdown list.

Size (AlCode Word): Select a size for

that type of conductor for comparison.

Aluminum Area (mm2): The cross

sectional area of the Al only. Diameter (mm): Outside diameter of

the selected conductor size.

Rated Strength (kN): Rated maximum

tensile strength of the conductor.

Weight (kg/km): The unit weight of the

conductor.

DC Resistance at 20C (ohms/km):

Nominal DC resistance of the

conductor at 20C

AC Resistance at 25C/75C (ohms/km):

Nominal AC resistance of conductor at

25C and 75C

Conductors per phase: Number of conductor bundled in the phase

Circuits: Number of circuit to perform the line loss/CO2calculations.

Capacity ratings are dependent upon the environmental inputs:

Ampacity (A) at Temperature (C): User chooses a temperature at

which they want the ampacity calculated, based upon the inputted

environmental assumptions.

Ampacity (A) at Rated Operating Temp (C): Value is from the

database, shows the ampacity at the rated operating temperature of

the conductor, based upon the inputted environmental assumptions

Ampacity (A) at Maximum Temp (C): Value is from the database,

shows the ampacity at the rated operating temperature of the

conductor, based upon the inputted environmental assumptions

3

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Step 3: Impact of conductor properties

Data in this section is used

to show ampacity, temperature

and sag. Type: First conductor type is the base

conductor, will impact the rest of the

comparisons. (Suggest ACCC conductor.)

Size (AlCode Word): Impact the

calculated capacity of the conductor.

Aluminum Area (mm2): Impact the

calculated capacity of the conductor.

Diameter (mm): Impact the capacity, and the

wind load sags.

Rated Strength (kN): Determine if factor of

safeties on the conductor are being meant and

will impact the sags.

Weight (kg/km): Impact the sags. DC Resistance at 20C (ohms/km): Impact the line

loss comparison, can chose a lower resistance

conductors to make comparisons against.

AC Resistance at 25C/75C (ohms/km): Impacts

the resistance, these values are used to calculate

the resistance at any other calculated

temperature of the conductor

Conductors per phase: Impact the line loss calculations, the more

conductors per phase, the lower the overall resistance of the

circuit.

Circuits: Impacts the line loss calculations, the more circuits, the

more line losses will be calculated in the comparison.

Ampacity (A) at Temperature (C): Choosing a specific

temperature, can show differences in ampacity at differenttemperatures that might be a larger interest to the user than the

rated and maximum temperatures.

Ampacity (A) at Rated Operating Temp (C): Can be used to

compare what the rated capacities will be.

Ampacity (A) at Maximum Temp (C): Can be used to compare

what the absolute maximum capacity of the line could be.

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Step 4: Setting initial sag conditions

The project conditions for initial sag, tension and installation temperature will allow CCP

to calculate the sags at various operating conditions.

Ruling Span (m): The approximate average distance between two towers for each line section

used to determine all sags and tensions within that section. Larger spans in the section willinfluence this calculation the most.

Initial Sagging Temperature (C): The expected ambient temperature when initially stringing the

line.

Maximum Allowable Sag (m): Based on clearance requirements.

% RTS: The tension at initial sagging based on the rated tensile strength (RTS) of the conductor.

Can also be considered Ultimate Tensile Strength (UTS) and Rated Breaking Strength (RBS).

Sag at Initial Sagging Temperature (m): This number is calculated based on the initial tension in

the conductor.

Initial Tension as Sagging Temperature (kN): This number is calculated based on the percent RTS

of the conductor chosen at a given temperature.

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Step 4: Impact of Initial Sagging Conditions

The initial tension, ruling span and installation temperature will have a significant

influence on the sags and the knee point temperature of the selected conductor.

Ruling Span (m): Set by the number of towers in a section of the line. The selection of a ruling can be affected

by clearance requirements, tower cost/height/strength, and conductor properties. The economics impact ofthe ruling span on a project are a complicated trade off of all of these factors.

Initial Sagging Temperature (C): The initial temperature is used as a basis to calculate sags at all other

temperatures. The impact of installation temperature needs to be considered for initial tension and final sag

conditions.

Maximum Allowable Sag (m): Based on clearance requirements, maximum sag may limit the ampacity of a

conductor with high thermal sag. This will impact each conductor individually.

% RTS: Ensure tension on the conductor does not exceed regulated limit, such as factor of safety thatdetermine the maximum tensions the conductor can exhibit under specific weather conditions.

Sag at Initial Sagging Temperature (m): Shows what the initial ruling span sag should be when the conductor is

newly installed.

Initial Tension as Sagging Temperature (kN): Shows the tension the conductor will exhibit when its first

installed.

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Step 5: Set wind and ice conditions & Impacts

Ice/wind conditions typically cause

the largest loading on the towers.

Temperature (C): Temperature at which the worst

loading case (either ice or wind) would exist.

Windspeed (km/hr): Speed of the wind for a

specific worst weather case.

Safety Factor (N/m): An additional weight added

to the conductor to build in a factor of safety to

ensure the maximum tension on the towers is notexceeded.

Radial Ice Thickness (mm): The thickness of ice

formed on the line for a specific worst weather

case. This adds additional weight to the

conductor.

Ice Density (kg/m3): The density of ice during the

specific worst weather case.

These calculations do not consider dynamic

forces that affect the line, hardware or

appropriate safety factors for a project. These

strictly relate to the weather impact on sag

clearance.

Typical Range and Impact of Changes.

Temperature (C): The colder the weather, the moretension there is on the conductor.

The temperature should be equal to the expected

ambient temperature, not the operating temperature.

Windspeed (km/hr): The wind speed is translated into

a unit weight that is added to the conductor weight,

and adds additional sag and tension to the conductor.

Safety Factor (N/m): Typically set by country or utilityrequirements.

Radial Ice Thickness (mm): Set by regulatory

requirements.

Ice Density (kg/m3): Set by regulatory requirements.

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Step 6: Evaluate line loss reduction and benefits

CCP uses the resistances of

the cables to calculate the

differences in temperature,line losses and CO2emission

Steady-State Temperature at

Peak Ampacity: Temperature of the conductor when operating at peak operating amps. Large differences in

temperature will lead to differences in line losses/CO2emissions between the selected conductors.

First Year Line Losses (MWh): The amount of line losses generated for the selected conductor. Is based upon the line

length, number of conductors per phase, the number of circuits, the resistance of the cable at the calculated

temperature and the load (loss) factor.

Comparisons are based on the conductor in the first column. When the number is positive, means the base conductor is

reducing the line losses/CO2generated over the other selected conductor. When the number is negative, means the base

conductor is increasing the line losses/CO2generated over the other selected conductor.

Base Conductor Reduces First Year CO2Generated by (MT): Shows the difference in the amount of CO2generated vs.

the base conductor.

Base Conductor Reduces First Year Line Losses by (MWh): Shows the difference in MWh the base conductorreduces/increases the line losses by.

Base Conductor Reduces First Year Line Losses by (%): Shows the difference, in percentage, the base conductor

reduces/increases the line losses by.

Base Conductor Reduces First Year Line Losses by ($/Year): Shows the amount of money the base conductor would

save/not save over the other conductors.

Base Conductor Line Loss Savings per meter of Conductor ($/m): Shows the line loss savings on a per meter of

conductor basis.

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Step 7: Sag/Tension Calculations & Impacts

CCP uses manufacturers

specifications and wire files to

calculate the operating sag of the

conductor.

Sag at Peak Operating Amps (Temp/Sag/Tension):

Shows the sags for the selected conductors at the

user specified peak operating amps. The colors

coordinate with the values found in sections 3 & 6.

Sag at Rated Operating Temp (Temp/Sag/Tension):

The sag at the rated operating temperature of theselected conductors.

Sag at Maximum Temp (Temp/Sag/Tension): The sag at

the maximum operating temperature of the selected

conductors.

Temperature at Maximum Allowable Sag (Max.

Temp/Sag/Tension/Ampacity): Shows the temperature

at which the selected conductor reaches the maximumallowable sag, set by the user in section 5. Ampacity

values turn red when the selected conductors

maximum capacity cannot be reached due to being sag

limited.

Wind/Ice or Cold Temperature Sag/Tension

(Sag/Tension): Shows the sag for the ice/wind condition

specified by the user inputs.

Impacts of these sag/tension calculations:

Results show the differences in the sags of the

selected conductors at key temperatures

Show the impact of limiting the sags, and how the

limit may reduce the maximum capacity of the

selected conductor in order to ensure clearances arenot violated

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Step 8: Visual sag presentation at temperature

A graphical representation of the sags as a

function of temperature, driven by

ampacity and maximum allowed

conductor temperature.

Shows the sags for the three conductors

selected

The bend in sag graph shows the location of

the knee point temperature

Below the knee point, the conductor

sags are dictated by the composite

conductor properties

Above the knee point, the conductor

sags are dictated by the core properties

alone

Sags are only shown for the range of

temperatures the conductor is rated to.

The maximum sag line is also shown, to

demonstrate where the potential sag limit

may be and how it will impact conductor

performance.

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Step 9: Understand the long term impact

CCP performs basic 30 year line loss calculations and can calculate the potential revenue

when operating at peak amps for a certain number of hours per year

Base conductor Reduces 30 Year Line Losses by ($): Calculation is determined by the user inputted

year load increase, allows all conductors to grow in load until the maximum use temperature of the

base conductor is reached, and then cuts off the load growth. Calculation shows the differences in

the line loss savings between the base and selected conductors over a 30 year period with no

discount rate or NPV calculation performed.

Base Conductor Reduces 30 Year CO2Generated by (MT): As with the 30 year line loss calculation,

performs the same calculation for the CO2reduction.

Peak Power Available for Delivery (User inputted hrs.) (MWh): This peak capacity is determined by

the sag limitation shown in section 8. Calculation shows the peak power that is delivered at the end

of the line, minus the line losses over the line at peak capacity.

Potential Revenue for Power Delivered ($): Utility may charge a different selling price when the line

is operating at peak capacity. Knowing what the peak power delivered potential can be, is multiplied

by the cost of selling the power while at peak capacity. Shows differences in revenue each conductor

choice can achieve.

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Step 10: Thermal Knee Point Calculation

CCP can calculate the thermal knee point temperature of each of the selected conductorsAll Bi-metallic conductors have a thermal knee point temperature

For conventional ACSR, the thermal knee point is typically above its maximum use

temperatureOther high temperature, low sag conductor types, this knee point transition typically occurs

within the operating range of the conductor

Thermal Knee Point is not a set value though, it is dependent on several factors:

1) Al/core area ratio

2) Span length (or ruling span length)3) Initial installation tension on the conductor

Thermal Knee Points results are:

A) Temperature at which the thermal knee point occurs at

B) The sag at the thermal knee point

C) The tension at which the thermal knee point

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Additional CTC Application Engineering Support

The Application Engineering Group at CTC Global is ready to support your project in

a number of ways. Once a project questionnaire is received, which is also embedded into the CCP program, the

application engineering team will begin the process of selecting the best conductor for the project,

whether its a reconductoring or new line project

First evaluate the capabilities of the old conductor and looking at the project goals, determine which

ACCC option could potentially meet the requirements

Can perform sag/tension calculations based on known stress-strain curves for nearly every conductortype, using either PLS-CADD or Sag10 software packages, and verify the sags shown on CCP are close

to what these software programs would calculate for similar starting sagging conditions.

Once conductors are chosen, write up a technical summary of which conductors CTC Global feels can

meet the project requirements and send analysis back to the customer who requested the analysis.

Once a project is identified as being a potential project for the ACCC option, application engineers

can directly communicate with the engineer of the project to help with any additional analysis or

answer technical questions about the ACCC option for the project

CTC Global Application Engineers though are not line designers, but are able to help facilitate the

choice of using an ACCC option for a project

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