icea.docx
TRANSCRIPT
ICEA/NEMA Standards Summary:The National Electrical Manufacturers Association (NEMA) publishes the ICEA wire and cable standards applications, and some of the new standards carry NEMA numbers also. New ICEA/NEMA Standards:ICEA S-93-639/NEMA WC74 Shielded Power Cable 5-46 kVICEA S-94-649 Concentric neutral cables 5-46 kVICEA S-95-658/NEMA WC70 Nonshielded 0-2kV CablesICEA S-96-659/NEMA WC71 Nonshielded 2001-5kV CablesICEA S-97-682 Copper tape shield, LCT, or drain-wire shielded cables 5-46 kV Withdrawn ICEA/NEMA Standards:ICEA S-19-81/NEMA WC3 Rubber-Insulated Wire and CableICEA S-61-402/NEMA WC5 Thermoplastic-Insulated Wire and CableICEA S-66-524/NEMA WC7 Cross-Linked-Thermosetting-Polyethylene Insulated Wire and CableICEA S-68-516/NEMA WC8 Ethylene-Propylene-Rubber Insulated Wire and Cable
ICEA Changes Cable Standard Strategy - January/February 2002
The winds of change are blowing. For years, cable buyers have called out Insulated Cable Engineers Association
(ICEA) standards to specify power and control cables. Now ICEA is replacing those familiar standards, along with
electric utility standards that have also been used for many medium voltage industrial applications.
"If you use references to ICEA standards to buy MV power cable, you'll need to update your specifications," says
Dave Mercier, technical director of Southwire's Electrical Division.
New standards are organized differently
ICEA standards include requirements for conductors, insulation, coverings, and construction details for wires and
cables. Buyers also call out ICEA standards to specify requirements such as dc voltages for field tests, emergency
overloads and minimum bending radii.
The key difference in the new ICEA standards is the way they are organized. The old organization called out separate
standards for polyethylene, ethylene propylene rubber and other insulation materials. The new standards are
organized by application. For example, a single document now covers 5kV - 46kV shielded power cables. "The
advantage is that all insulations suitable for a specific application are now in a single document," Mercier says.
The new ICEA standards also reflect the latest cable construction technologies, including improvements in the ability
to manufacture "round" cables. The new standards define insulation thickness and eccentricity by minimum and
maximum allowable values, which assures a more "round' cable than the old standards. The old nominal average
thicknesses - such as 220 mils - are used only as a reference and for cable identification.
AEIC supplements change also
Many industrial cable specification writers also refer to AEIC cable specifications for the qualification testing those
standards require. Because the new ICEA standards now include some qualification tests, AEIC has rewritten their
standards to supplement the new ICEA standards. A single new specification - AEIC CS-8 - replaces AEIC CS-5 for
XLPE and AEIC CS-6 for EPR insulation.
"If your specifications include CS-8 qualification testing, word the reference to make it clear that the only applicable
part of the CS-8 standard is the qualification-testing portion," Mercier says.
The minimum requirement when using cable under the NEC remains UL 1072, "Safety Standard for Medium-Voltage
Power Cables." The third edition of UL 1072 will incorporate the majority of the changes in the ICEA standards.
"Southwire has always been active in the industry's standards process," says Mercier. "We've participated in
development of the new ICEA standards, we're involved in the ongoing NEC process. It's all part of bringing the best
wire and cable products to our customers."
IEC 60287 "Calculation of the continuous current rating of cables (100% load factor)" is the International
Standard which defines the procedures and equations to be used in determining the current carry
capacity of cable. The standard is applicable to all alternating current voltages and direct current cables
up to 5kV.
This note will introduce the concepts adopted by the standard, provide some guidance on using the
standard and direct the reader to further resources.
Contents [hide]
1. Thermal Problem
2. The Standard in More Detail
3. Applying the Standard
4. Other Related Resources
5. Summary
Thermal Problem
Principle- simple wire in homogeneous material The methodology taken to the sizing of cables is that of treating the issue as a thermal problem.
Losses within a cable will create heat. Depending on the installation conditions this heat will be
dissipated to the surrounding environment at a given rate. As the cable heats up rate of heat dissipation
will increase.
At some temperature the rate at which heat is being dissipated to the environment will be the same as the
rate at which it is generated (due to loses). The cable is then in thermal equilibrium.
The losses (and heat generated) are dependent on the amount of current flowing within the cable. As the
current increases the losses increase and the thermal equilibrium temperature of the cable will increase.
At some given current level, the cable temperature at thermal equilibrium will equal the maximum
allowable temperature for the cable insulation. This is the maximum current carrying capacity of the cable
for the installation conditions depicted by the calculation.
To illustrate the principle, we can consider a simplistic scenario of a d.c. cable (as shown in the
illustration), surrounded with an insulating material and placed in a homogeneous thermal conducting
material.
Given:
I - conductor current, A
R' - d.c. resistance of the conductor per unit length, Ω/m
Θ - maximum conductor operating temperature, °C
Θa - ambient temperature, °C
ΔΘ - temperature difference (Θ-Θa), K
T - thermal resistance per unit length between conductor and surrounding, K.m/W
The losses (watts per unit length) generated by the conductor is given by:
The heat flow (watts per unit length) from the conductor is given by:
At thermal equilibrium these will be equal and can be rearranged to give the cable current carrying
capacity (in Ampere):
As an example, consider finding the current carrying capacity of a 50 mm2 conductor, with XPLE
insulation directly buried (with an insulation thermal resistance of 5.88 K.m/W and soil thermal thermal
resistance of 2.5 K.m/W) and at an ambient temperature of 25 °C
by using the related resources links given at the end of the posts, we are able to find the
following:
the dc resistance of the cable is 0.387 mΩ/m
the maximum allowable temperature for XLPE insulation is 90 °C
and a total thermal resistance of 5.88+2.5 = 8.38 (insulation, plus soil)
ΔΘ = 90-25 = 65 K, giving
I = √ [65/(0.000387*8.38)] = 142 A
The Standard in More Detail
Applying the IEC 60287 Standard (click to enlarge) The reality of any cable installation is more complex than described above. Insulating materials have dielectric losses, alternating current introduces skin effect, sheath and eddy current losses, several cables are simultaneously producing heat and the surrounding materials are non-homogeneous and have boundary temperature conditions.
While the standard addresses each of these issues, the resulting equations are more complex do take
some effort to solve. Anyone attempting to apply this method should be working directly from a copy of
the standard. As an overview, the standard looks at the following situations:
differences between alternating and direct current systems in calculating cable
capacity
critical temperatures of soil and possible requirements to avoid drying out the soil
cables directly exposed to solar radiation
calculation of the a.c. and d.c. resistance of conductors (including skin effect,
proximity effect and operating temperature)
insulation dielectric losses
conductor I2R losses
losses in sheaths and screens (including flat, trefoil and transposed formations)
circulating current losses (including sheath, armour and pipes)
thermal resistance (and it's calculation)
Each of these areas is discussed in more detail in the following posts (which together form a
comprehensive guide to the standard):
The dc resistance of conductors - calculation of the d.c. resistance of cables
The ac resistance of conductors - calculation of the a.c. resistance of cables
Dielectric loss in cables – calculation of dielectric losses
Cable Sheath and Armour Loss – calculation of sheath and armour losses
IEC 60287 Current Capacity of Cables - rated current
Applying the StandardWithin the standard there are a lot of equations and it can be confusing to persons who are new to the
method. However a step by step working through it approach will enable the current carrying capacity to
be calculated. The flow chart shows one recommended path for working through a cable sizing exercise
in line with the standard.
Given the number of equations which need to be solved, it is tedious to calculate in accordance with the
standard by using hand or manual methods. More practically software applications are used, which allow
the sizing of cables to take place quickly. A quick Google search will turn up several software programs
capable of performing the calculation.
Tip: a cable run can move through different installation environments (for example it may
start in a cable basement, more through ducts in a wall, be buried for some of the route,
suspended under a bridge, buried again, through ducts and into the receiving building). In
this instance the current capacity should be evaluated for each type of installation condition
and the worse case taken.
Other Related ResourcesCable Sizing Tool - describes the procedure for the sizing of cable to BS 7671 and IEC 60364
Standard Cable & Wire Sizes - list of standard IEC 60228 wire sized and AWG conversion table
8 Steps to Low Voltage Power Cable Selection and Sizing - general guide to selecting/using LV
cables
Cable Insulation Properties - typical properties of various types of cable insulation
SummaryWithin the note the IEC 60287 have been introduces and the problem of finding the current capacity of a
cable boiled down to that of a thermal calculation. The note has given an overview of the contents of the
standard, ways to navigate and perform the calculation and provided links to more detailed posts.
Hopefully the note has achieved the objective of providing an introduction to the current capacity sizing
methods of IEC 60287. If you have any comments or something is not clear enough, please post these
below.
- See more at: http://myelectrical.com/notes/entryid/207/iec-60287-current-capacity-of-cables-an-introduction#sthash.AyqqPb27.dpuf
IEC 60287 Current Capacity of Cables - Rated Current By Steven McFadyen on February 18th, 2013
This note looks at the formulae used to calculate the rated current capacity of a cable in line with IEC
60287 "Calculation of the continuous current rating of cables (100% load factor)". Before you continue
reading this note, if you have not done so already we would suggest first reading our IEC 60287
introduction note:
IEC 60287 Current Capacity of Cables - An Introduction
In the previous note we looked at the approach taken by the standard to the sizing of cables and
illustrated this with an example. We then looked at one method of applying the standard and identified
resources enabling the calculation of all the various parameters involved. In the note we are going to put
everything together and reveal the necessary equations for actually calculating the cable maximum
current rating.
The image illustrates the thermal model for a cable.
Heat is generated within the cable by various mechanisms - conductor I2R loss, dielectric loss, sheath
loss, armour loss and direct solar radiation. Some or all of this heat is dissipated through the cable
insulation, bedding, serving and into the surrounding medium. The rate of heat flow is related to the
temperature difference across the cable and affected by the ambient temperature, temperature rises due
to other cables and any critical temperature rise of the soil above ambient.
In thermal equilibrium, when all these factors have balanced and the temperature of the conductor is the
maximum allowable for the insulation; we have the maximum rated current for the cable. It can probably
be appreciated by now, that in typical real life situations, this can be quite a complicated calculation.
Note: rated current capacity found by the method assumes that the cable is fully loaded for
100% of it's operation time. For cables which have varying or cyclic loads, the current
rating could possibly be increased.
Tip: the thermal model is worth remembering as enables us to intuitively understand how a
cable is likely to behave in conditions which are not normally encountered. For example, if
a cable is run along a refrigerated gas pipe, we can hazard that this will reduce the ΔΘ and
hence the cable will be able to carry more current.
Change in temperature across a material is equal to the heat input multiplied by the thermal resistance of
the material. In terms of the thermal model and for a simple a.c. cable, the heat balance equation is given
by (a list of symbols is given at the end of the note):
Within the standard this above is used to derive the equations for current rating. It is simplified for d.c.
cables by eliminating any a.c. only effects and modified for partial drying of soil and solar radiation where
appropriate.
Contents [hide]
1. Rated Current of Cables
2. List of Symbols
Rated Current of CablesThe standard gives the following equations for the calculation of the cable current rating (for all alternating
current voltages and direct current up to 5 kV):
Buried cables where drying out of the soil does not occur or cables in air
AC cables
DC cables
Buried cables where partial drying-out of the soil occurs
AC cables
I=[Δθ−Wd[0.5T1+n(T2+T3+vT4)]+(v−1)ΔθXR[T1+n(1+λ1)T2+n(1+λ1+λ2)(T3+vT4)]]0.5
DC cables
I=[Δθ+(v−1)ΔθXR′[T1+nT2+n(T3+vT4)]]0.5
Buried cables where drying-out of the soil is to be avoided
AC cables
I=[Δθx−nWdT4nRT4(1+λ1+λ2)]0.5
DC cables
Cables directly exposed to solar radiation
AC cables
DC cables
Note: when calculating a cable where some drying of the soil may occur, it is also
necessary to perform the calculation for no drying out of soil and take the worse case
(lower) rating.
The calculation of each element needs some explanation and these have been split across several notes
(with each note dealing with one topic). For details, please refer to the first note in this series, which
lists the other related notes.
List of Symbolsn - number of load carrying conductors
v - ratio of thermal resistivity of dry and moist soils
I - rated conductor current, A
R - a.c. resistance of the conductor per unit length, Ω/m
R' - d.c. resistance of the conductor per unit length, Ω/m
T1 - thermal resistance per core between conductor and sheath, K.m/W
T2 - thermal resistance between sheath and armour, K.m/W
T3 - thermal resistance of external serving, K.m/W
T4 - thermal resistance of surrounding medium, K.m/W
T4* - external thermal resistance (free air) adjusted for solar radiation, K.m/W
De* - cable diameter over insulation, m
H - intensity of solar radiation, W/m2
Wd - dielectric loss per units length, W/m
λ1 - ratio of losses in metal sheath to total losses in all conductors
λ2 - ratio of losses in armouring to total losses in all conductors
σ - absorption coefficient of solar radiation for cable surface
Θ - maximum conductor operating temperature, °C
Θa - ambient temperature, °C
ΔΘ - temperature difference (Θ-Θa), K
ΔΘx - critical temperature of soil, °C- See more at: http://myelectrical.com/notes/entryid/210/iec-60287-current-capacity-of-cables-capacity-equations#sthash.JdE1IgQN.dpuf
By Steven McFadyen on July 24th, 2011
A recurring theme on our forums is cable sizing. Now many installations are unique and require special consideration. However, a lot of the time things are just repeated. When looking at low voltage power cables I generally always start with the same basic strategy.
1. Default to using XLPE - why bother with other insulations (PVC, rubber, etc.). XLPE is
well established, cost competitive and doesn't have any of the degradation or fire
related issues of other insulations. You will also end up with a smaller cross sectional
area. Only in special circumstances would you need to look at other installation
types.
2. Use armoured - buried cable mechanical protection is essential. For indoor cables the
use of armouring is not essential, however you have the benefit of using the
armouring for the CPC. On indoor cables, perhaps make the choice of armoured or
not dependant on local practice.
3. Use LSZH (low smoke zero halogen) sheath - smoke and toxic fumes in a fire situation
are not good. Why not just avoid the issue.
4. Calculate the current rating using an acceptable method. I tend to use the method
given in BS 7671 as this is generally applicable where I work. Calculate the rating
taking into account both the design current and protective device rating and apply the
necessary derating factors.
5. Calculate the voltage drop - again I tend to use BS 7671 and check it complies with
local regulations. The voltage drop needs to be the sum of all cables in a circuit (from
source to end load).
6. Ensure the cable can take the fault level - for most larger cables this tends not to be a
problem, but for smaller cables it can be an issue.
7. Use software - if possible use approved software to do items 4 to 5. It makes life
easier. Two which come to mind are the myElectrical cable sizing tool and AMTECH.
8. Be practical - make sure your cable size is reasonable. If you end up with a 120
mm2 cable on a 2 A load due to meeting voltage drops or fault levels start to look a the
system design concept itself.
while you cannot say "once you have selected one cable you have selected all cables', you
may be able to get away with saying "once you have selected a few cables you have
selected most cables"
Finally we need a disclaimer here. While the above is good for most situations (low voltage power), it
does not cover every case. There are situations which are different, unique or require some special
consideration. To address these situations, one of the best things is to understand fully the
characteristics of the load the cable will be supplying, the environment it is being installed in and be aware
of other overriding issues. If you can do this, any necessary adjustments to the eight point plan often
become obvious.
- See more at: http://myelectrical.com/notes/entryid/73/8-steps-to-low-voltage-power-cable-selection-and-sizing#sthash.ulcd8Vk2.dpuf
Calculation of Sheath and Armour LossAny cable sheath (or screen) the loss λ1, consists of two components:
λ1=λ1''+λ1''
λ1' - losses caused by circulating currents. These losses only occur in single core
cables and for any circulating current to be present, it is necessary to the sheaths of
each cable to be bonded at two or more points along its length.
λ1'' - losses caused by eddy currents. These are small circulating currents setup in
the sheath due to changing magnetic fields.
The loss in armour is considered as only one component, λ2.
Sheath and armour losses are only applicable to alternating current (a.c.) cables. The actual formula for
calculation of sheath and armour loss depend on the installation and arrangement of cables. The tables
below presents some of the common installation situations and are based on equations given in IEC
60287:
Calculation of sheath or screen loss in - Single Core CablesFor installations bonded only at one point, circulating currents are not possible and the loss is zero.
Except in the case of large segmental type conductors (see Some Special Cases below), eddy current
loss λ1'', for single core cables can be ignored.
Sheath Circulating Current Loss, λ1'
Single core cables
- trefoil, bonded at both ends
λ1′=RSR11+(RsX)2
Single core cables
- flat, with transposition,
bonded at both ends
λ1′=RSR11+(RsX)2
Single core cables
- flat, without transposition,
bonded at both ends
λ11′ - loss factor for the outer cable with the greater losses
λ11′=RsR[0.75P2Rs2+P2+0.25Q2Rs2+Q2+2RsPQXm3√(Rs2+
P2)(Rs2+P2)]
λ12′ - loss factor for the outer cable with the least losses
λ12′=RsR[0.75P2Rs2+P2+0.25Q2Rs2+Q2−2RsPQXm3√(Rs2+
P2)(Rs2+P2)]
λ1m′ - loss factor for the middle cable
λ1m′=RsRQ2Rs2+Q2
where:
P=X+Xm
Q=X+Xm3
Calculation of sheath or screen loss in - Multi-Core CablesDue to any sheath or screen surrounding all cores, the possibility of circulating current does not exist, and
the λ1' loss can be ignored. Eddy current loss, λ1'' does need to be considered.
Sheath Eddy Current Loss, λ1''
Two core cable - common sheath,
unarmoured
- for round or oval conductors
λ1''=16ω210−14RRs(cd)[1+(cd)2]
- for sector shaped conductors
λ1''=10.8ω210−16RRs(1.48r1+td)[12.2+(1.48r1+td)2]
Three core cable - common sheath,
unarmoured
- round or oval conductors, Rs ≤ 100 µΩ.m-1
λ1''=3RsR⎡⎣⎢⎢(2cd)211+(Rsω107)2+(2cd)411+4(Rsω107)2⎤⎦⎥⎥
- round or oval conductors, Rs >100 µΩ.m-1
λ1''=3.2ω2RRs(2cd)210−14
- for sector shaped conductors (any Rs)
λ1''=0.94RsR(2r1+td)211+(Rsω107)2
Two or three core cable - steel tape armour Multiple the unarmoured cable factor by:
⎡⎣⎢1+(ddA)211+dAμδ⎤⎦⎥2
Cables with each core in a separate sheath or
pipe type cables
λ1''=RsR1.51+(RsXSL)
where:
XSL=2ω10−7ln(2cd)
Calculation of armour lossFor armoured cables, the losses are estimated as shown.
Armour Loss, λ2
Non-magnetic armour Use equation for λ1'', substituting:
parallel combination of sheath and armour resistance for Rs
root mean square of sheath and armour diameter for d
Single core cables - steel
wire armour
General advice is not to use magnetic armour for single core cables.
If required, then the guidelines given in IEC 60287 on estimating losses
should be followed.
Two core cable - steel
wire armour λ2=0.62ω210−14RRA+3.82Aω10−5R[1.48r1+tdA2+95.7A]2
Three core cable - steel
wire armour
- round conductor
λ2=1.23RAR(2cdA)21(2.77RA106ω)2+1
- sector shaped conductor
λ2=0.358RAR(2r1dA)21(2.77RA106ω)2+1
Calculating the ParametersSheath (Rs) or armour (RA) resistance - values used above are calculated at their operating
temperature. The operating temperature (in °C) and resistance can be determined from:
θsc=θ−(I2R+0.5Wd)×T1
- for any sheath
θar=θ−{(I2R+0.5Wd)×T1+[I2R(1+λ1)+Wd]×nT2}
- for any armour
Rs=Rs20[1+α20(θsc−20)]
- for the cable sheath
RA=RA20[1+α20(θar−20)]
- for the cable armour
Note: for calculation of the dielectric loss Wd, refer to our Dielectric loss in cables note.Cable Reactance - for single core cables, where there is significant spacing between conductors, it is necessary to use the reactance in the calculating of circulating current loss. Accurate values for reactance can be obtained from cable manufacturers or by using software. Alternatively, the following equations can be used to estimate the reactance (Ω.m-1):
Single core cable reactance estimates (assume bonded at both ends)
X=2ω10−7ln(2sd)
- trefoil or flat without transposition
X=2ω10−7ln(232√sd)
- flat with transposition
Xm=2ω10−7ln(2)
- mutual reactance of flat formation cables
Steel tape armour resistance - depending on how steel tape is wound, the resistance can be estimated as follows:
1. tapes laid longitudinally - calculate the resistance as that of an equivalent cylinder
(same mass and diameter)
2. tapes laid ≈54° to cable axis - use twice the value obtained from (1)
3. tapes with a very short lay - take resistance as infinite (neglect losses)
4. tapes with a very short lay (double layered) - use twice the value obtained form (1)
Cable TranspositionTransposing of cables (see image) is a technique to reduce the circulating currents within cable sheaths
and consequently increase the rating of the cable.
Transposed and cross bonded cable
By cross bonding the sheath the induced currents are in opposite directions, cancelling each other out
and significantly improving the current rating of the cable. Transposing the cables ensures that the
reactance balance out and aids in implementation.
At intermediate transposition points, over voltage devices are installed to protect the cable and personnel
in the event of voltage build up during faults.
In practice, three minor sections (part between the cross bond) would from a major section (three full
transpositions). It makes sense to do these at each joint point - at each cable drum length.
Transposition and cross bonding are normally carried out in link boxes.
Some Special Situations
Large segmental type conductorsEddy current losses λ1'', are normally small relative to other losses and can be ignored for single core
cables. This changes for large conductors, which are of a segmented construction. Under these
conditions, the eddy current loss should be considered.
For this condition, the value of λ1'' is derived from the circulating current loss factor λ1' by:
λ1''=λ1′×4M2N2+(M+N)24(M2+1)(N2+1)
where:
M=N=RsX
- for cables in trefoil
M=RsX+Xn and N=RsX−Xm3
- for cable in flat formation
Single core cables - variation of route spacingIf the spacing if not maintained the same for the full cable route than the reactance will vary along the
route. In instances such as these, an equivalent overall reactance can be calculated from:
X=laXa+lbXb+…+lnXnla+lb+…+ln
- where la, lb, ... are the section lengths and Xa, Xb, ... are the reactance of each section
SymbolsA - armour cross sectional area, mm2
R - conductor a.c. resistance, Ω.m-1
RA - armour resistance maximum at operating temperature, Ω.m-1
RA20
- armour resistance at 20 °C, Ω.m-1
Rs - sheath or screen resistance at maximum operating temperature, Ω.m-1
Rs20
- sheath or screen resistance at 20 °C, Ω.m-1
X - sheath or screen reactance, Ω.m-1
Xm - mutual reactance (sheath one cable to conductors of other cables), Ω.m-1
λ1
- ratio of sheath loss to total conductor loss
λ2
- ratio of armour loss to total conductor loss
λ1' - sheath loss caused by circulating currents
λ1''
- sheath loss caused by eddy currents
c - distance between axis of conductors, mm
d - mean diameter of sheath or screen, mm
dA
- mean diameter of armour, mm
r1 - circumscribing radius of sector shaped conductors, mm
s - axial separation of conductors, mm
t - insulation thickness between conductors, mm
T1
- thermal resistance between conductor and sheath, K.m.W-1
T2
- thermal resistance between sheath and armour, K.m.W-1
θ - maximum conductor temperature, °C
θar
- maximum operating temperature of armour, °C
θsc
- maximum operating temperature of screen, °C
ω - angular frequency (2πf)
µ - relative magnetic permeability of armour
δ - equivalent thickness of armour, mm
See Also- See more at: http://myelectrical.com/notes/entryid/235/cable-sheath-and-armour-loss#sthash.f0inMMXr.dpuf
Cable Sizing Tool By Steven McFadyen on May 20th, 2012
Our cable sizing tool is one of the more popular tools on the site. The tool enables cables to be sized in compliance with BS 7671 (the IEE Wiring Regulations) and by implication IEC 60364.
This post gives some insight into how the tool works, the calculations carried out and how to use it. With
the tool being based on BS 7671, this post will also provide an introduction and explanation of the cable
sizing method given in the standard.
The sizing tool can be found at:
myElectrical Cable Sizing Tool
Contents [hide]
1. The Procedure
2. The Formulae
1. Current Capacity
2. Voltage Drop
3. Fault Levels
3. Frequently Asked Questions
The ProcedureThe flowchart (click for a larger image) shows the general procedure followed by the tool:
current capacity – a cable size is found which is adequate for the expected current
voltage drop – the voltage drop on the selected cable is checked and if to big the cable
size is increased
fault level – the fault level withstand is checked and if not adequate the cable size is
increase
Any errors or warnings generated during the calculation are passed on the the user.
In addition to cable size the tool also calculates the cable impedance and fault levels at the load end of
the cable.
The FormulaeThe calculation method follows the procedures given in BS 7671:2008 (the IEE Wiring Regulations), 17th
Edition.
Definitions:
Iz - current carrying capacity of the cable (continuous service under defined installation
conditions)
It - tabulated value of current (for the type of cable, type of installation, and at an ambient of
30oC)
Ib - design current of the circuit (expected in normal service)
In - nominal setting of any protective device
I2 – operating current of the protective device
Ca - correction factor for the ambient temperature
Cc - correction factor for the type of protective device used
Cg - correction factor for grouping of circuits/cables
Ci - correction factor thermal insulation
Ct - correction factor for the operating temperature of the conductor
Np - number of cables in parallel
tp - maximum permitted operating temperature
Current CapacityBy considering any correction factors, the tabled current for a cable installed in a given situation can be
found. Once the tabled value of current is found, the cable size is determined by selecting the next
largest cross sectional area in the lookup tables.
For single circuits:
For groups where simultaneous overload is possible:
For groups not liable to simultaneous overload (the maximum of):
For cables where overload protection is not required:
Once It is known, this size of cable is then looked up in the current carrying capacity tables:
Tables 4D1A to 4J4A (pages274 to 316) – current carrying capacity
Correction factors are obtained from the following tables (dependant upon cable type and installation):
Table 4B1 – rating factors for cables in air, ambient other than 30 °C
Table 4B2 – rating factors for buried cables, ambient other than 20 °C
Table 4B3 – rating factors for buried cables, thermal resistivities other an 2.5 K.m.W-1
Table 4C1 to 4C3 – rating for grouping of circuits/cables
Table 52.2 – rating factors for cables surrounded by thermal insulation
Voltage DropVoltage drop calculations consider both the power factor of the system and a correction factor for the
cable operating standard. Tables 4D1B to 4J4B of the standard give voltage drops (resistive and
reactive) in (mV/A/m), which is equivalent to mΩ/m (or Ω/m if adjusted).
By looking up in these tables and using the cable length, the sizing tool determines the resistance, R and
reactance, X of the cable. The calculated voltage drop, is then given by:
The temperature correction factor is only applied to the resistance and is given by:
Note: the tool carries out all calculations in complex form.
Fault LevelsThe fault withstand rating of the cable is determined using the adiabatic equation:
Where:
S is the cable cross sectional area in mm2
I is the fault current which can flow in A
t is the operating time of the protective device in S
k is a factor related to the conductor material and insulation – tables 54.2 to 54.6 of the
standard- See more at: http://myelectrical.com/
By Steven McFadyen on May 15th, 2012
HDPE Cable Insulation
Resin
Cable insulation is used to provide electrical separation between conductors of a cable. During the
historical development of cables, numerous types of insulation have been employed. During recent years,
there has been some consolidation in the types of insulation used.
This post provides some information on the more commonly used cable insulation materials.
Contents [hide]
1. Insulation Materials (PVC)
2. Insulation Materials (PE)
3. Insulation Materials (other)
4. Elastomere Materials
5. High Temperature Materials
6. Halogen Free Compounds
7. See Also
Insulation Materials (PVC)Y Yw Yw Yk
PVC PVC PVC PVC
Polyvinylchlo
ride
Compounds
Heat-
resistant
90oC
Heat-
resistant
105oC
Cold
Resistant
Density g/cm3 1.35 - 1.5 1.3-1.5 1.3-1.5 1.2-1.
Breakdown Voltage KV/mm
(20oC)
25 25 25 25
Specific Volume Resistivity Ω
cm (20oC)
1013-1015 1012-1015 1012-1015 1012-1015
Dielectric Constant 50 Hz
(20oC)
3.6-6 4-6.5 4.5-6.5 4.5-6.5
Dielectric Loss Factor (tan δ) 4 x 10-2 to 1 x
10-1
4 x 10-2 to 1 x
10-1
4 x 10-2 to 1 x
10-1
4 x 10-2 to 1 x
10-1
Working Permanent oC -30 +70 -20 +90 -20 +105 -40 +70
Temperature Short Time oC +100 +120 +120 +100
Melt Temperature +oC >140 >140 >140 >140
Flame Resistance Self
Extinguishing
Self
Extinguishing
Self
Extinguishing
Self
Extinguishing
Oxygen Index LOI (% O2) 23-42 23-42 24-42 24-42
Heating Value H0 MJ.kg-1 17-25 16-22 16-20 17-24
Thermal Conductivity W.K-1.m-
1
0.17 0.17 0.17 0.17
Corrosive Gases In Case Of
Fire
Hydrogen
Chloride
Hydrogen
Chloride
Hydrogen
Chloride
Hydrogen
Chloride
Radiation Resistance max
Mrad
80 80 80 80
Tensile Strength N/mm2 10-25 10-25 10-25 10-25
Elongation At Break % 130-350 130-350 130-350 130-350
Shore Hardness 70-95 (A) 70-95 (A) 70-95 (A) 70-95 (A)
Abrasion Resistance Medium Medium Medium Medium
Water Absorption % 0.4 0.4 0.4 0.4
Halogen Free No No No No
Weather Resistance Medium
(Black: Good)
Medium
(Black: Good)
Medium
(Black: Good)
Medium
(Black: Good)
Cold Resistance Moderate - Moderate - Moderate - Very Good
Good Good Good
Insulation Materials (PE)2Y 2Y 2X O2Y
LDPE HDPE VPE
Low
density
Polyethyl
ene
High
density
Polyethyl
ene
Cross
Linked
Polyethyle
ne
Foamed
Polyethyl
ene
Density g/cm3 0.92-0.94 0.94-0.98 0.92 ≈0.65
Breakdown Voltage KV/mm
(20oC)
70 85 50 30
Specific Volume Resistivity Ω cm
(20oC)
1017 1017 1012-1016 1017
Dielectric Constant 50 Hz (20oC) 2.3 2.3 4-6 ≈1.55
Dielectric Loss Factor (tan δ) 2 x 10-4 3 x 10-4 2x 10-3 5 x 10-4
Working
Temperature
Permanent oC -50 +70 -50 +00 -35 +90 -40 +70
Short Time oC +100 +120 +100 +100
Melt Temperature +oC 105-110 130 - 105
Flame Resistance Flammable Flammable Flammable Flammabl
e
Oxygen Index LOI (% O2) ≤22 ≤22 ≤22 18-30
Heating Value H0 MJ.kg-1 42-44 42-44 42-44 42-44
Thermal Conductivity W.K-1.m-1 0.3 0.4 0.3 0.25
Corrosive Gases In Case Of Fire No No No No
Radiation Resistance max Mrad 100 100 100 100
Tensile Strength N/mm2 10-20 20-30 12.5-20 8-12
Elongation At Break % 400-600 500-1000 300-400 350-450
Shore Hardness 43-50 (D) 60-63 (D) 40-45 (D) -
Abrasion Resistance Medium Good Medium -
Water Absorption % 0.1 0.1 0.1 -
Halogen Free Yes Yes Yes Conditiona
l
Weather Resistance Medium
(Black:
Good)
Medium
(Black:
Good)
Good -
Cold Resistance Good Good Good Good
Insulation Materials (other)3Y 4Y 9Y 11Y TPE-E
(12Y)
TPE-O
PS PA PP PUR
Polystrol
e
Polyamid
e
Poly-
propylen
e
Poly-
urethan
e
PolYest
er
Elastom
er
Polyolefi
ne
Elastome
r
Density g/cm3 1.05 1.02-1.1 0.91 1.15-1.2 1.2-1.4 0.89-1.0
Breakdown Voltage 30 30 75 20 40 30
KV/mm (20oC)
Specific Volume
Resistivity Ω cm (20oC)
1016 1015 1016 1010-1012 >1010 >1014
Dielectric Constant 50 Hz
(20oC)
2.5 4 2.3-2.4 4-7 3.7-5.1 2.7-3.6
Dielectric Loss Factor
(tan δ)
1 x 10-4 2 x 10-2 to
1 x 10-3
4 x 10-4 2.3 x 10-2 1.8 x 10-2 1.8 x 10-2
Working
Temperatu
re
Permanent oC
-50 +80 -60 +05 -10 +100 -55 +80 -50 +100 -50 +100
Short
Time oC
+100 +125 +140 +100 +140 +130
Melt Temperature +oC >120 210 160 150 190 150
Flame Resistance Flammabl
e
Flammabl
e
Flammabl
e
Flammabl
e
Flammab
le
Flammabl
e
Oxygen Index LOI (% O2) ≤22 ≤22 ≤22 ≤22 ≤29 ≤25
Heating Value H0 MJ.kg-1 40-43 27-31 42-44 20-26 20-25 23-28
Thermal Conductivity
W.K-1.m-1
0.25 0.23 0.19 0.25 0.5 1.5
Corrosive Gases In Case
Of Fire
No No No No No No
Radiation Resistance
max Mrad
80 10 10 100 10 10
Tensile Strength N/mm2 55-65 50-60 20-35 30-45 30 20
Elongation At Break % 300-400 50-170 300 500-700 >300 >300
Shore Hardness 35-50 (D) - 55-60 (D) 70-100 85 (A), 55 (A), 70
(A) 70 (D) (D)
Abrasion Resistance Good Very Good Medium Very
Good
Good Good
Water Absorption % 0.4 1.0-1.5 0.1 1.5 1.5 1.5
Halogen Free Yes Yes Yes Yes Yes Yes
Weather Resistance Medium -
Good
Good Moderate Very
Good
Very
Good
Very
Good
Cold Resistance Moderate
- Good
Good Good Very
Good
Very
Good
Very
Good
Elastomere MaterialsG 2G 3G 4G 5G 6G
NR
SBR
SiR EPR EVA CR CSM
Natural
Rubber
Styrol-
Butadien
e
Rubber
Compoun
ds
Silicon
e
Rubber
Ethylen-
Propylen
e
Rubber
Compou
nds
Ethylene-
Vinylacet
ate
Copolyme
re
Compoun
ds
Poly-
Chloropre
ne
Compoun
ds
Chloro-
Sulfonate
d
Polyethyl
ene
Compoun
ds
Density g/cm3 1.5-1.7 1.2-1.3 1.3-1.55 1.3-1.5 1.4-1.65 1.3-1.6
Breakdown Voltage
KV/mm (20oC)
20 20 20 30 20 25
Specific Volume
Resistivity Ω cm (20oC)
1012-1015 1015 1014 1012 1010 1012
Dielectric Constant 50
Hz (20oC)
3-5 3-4 3-3.8 5-6.5 6-8.5 6-9
Dielectric Loss Factor
(tan δ)
1.9 x 10-2 6x 10-3 3.4 x 10-3 2 x 10-2 5 x 10-2 2.8 x 10-2
Working
Temperat
ure
Permanent oC
-65 +60 -60
+180
-30 +90 -30 +125 -40 +100 -30 +80
Short
Time oC
+120 +260 +160 +200 +140 +140
Melt Temperature +oC - - - - - +160
Flame Resistance Flammabl
e
High
Flash
Point
Flammabl
e
Flammable Self
Extinguishi
ng
Self
Extinguishi
ng
Oxygen Index LOI (%
O2)
≤22 25-35 ≤22 ≤22 30-35 30-35
Heating Value
H0 MJ.kg-1
21-25 17-19 21-25 19-23 14-19 19-23
Thermal Conductivity
W.K-1.m-1
- 0.22 - - - -
Corrosive Gases In
Case Of Fire
No No No No Hydrogen
Chloride
Hydrogen
Chloride
Radiation Resistance
max Mrad
100 50 200 100 50 50
Tensile Strength
N/mm2
5-10 5-10 5-10 8-12 10-20 10-20
Elongation At Break % 300-600 300-
600
200-400 250-350 400-700 350-600
Shore Hardness 60-70 (A) 40-80
(A)
65-85 (A) 70-80 (A) 55-70 (A) 60-70 (A)
Abrasion Resistance Moderate Modera Moderate Moderate Medium Medium
te
Water Absorption % 1.0 1.0 1.0 1.0 1.0 1.5
Halogen Free No Yes Yes Yes No No
Weather Resistance Moderate Good Very
Good
Good Very Good Very Good
Cold Resistance Very Good Very
Good
Good Good Moderate Moderate
High Temperature Materials10Y 7Y 6Y 5YX 5Y
PVDF ETFE FEP PFA PTFE
Polyvinylid
ene
Fluoride
Kynar/Dyfl
or
Ethylene-
Tetrafluoreth
ylene
Fluorine
Ethylene
Propylen
e
Perfluoral-
Koxypolym
eric
Poly-
Tetrafluoreth
ylene
Density g/cm3 1.7-1.9 1.6-1.8 2.0-2.3 2.0-2.3 2.0-2.3
Breakdown Voltage
KV/mm (20oC)
25 36 25 25 20
Specific Volume
Resistivity Ω cm
(20oC)
1014 1016 1018 1018 1018
Dielectric Constant
50 Hz (20oC)
9-7 2.6 2.1 2.1 2.1
Dielectric Loss
Factor (tan δ)
1.4 x 10-2 8 x 10-4 3 x 10-4 3 x 10-4 3 x 10-4
Working
Temperat
Permanen
t oC
-40 +135 -100 +150 -100 +205 -190 +260 -190 +260
ure Short
Time oC
+160 +180 +230 +280 +300
Melt Temperature
+oC
>170 >265 >225 >290 >325
Flame Resistance Self
Extinguishin
g
Self
Extinguishing
Self
Extinguish
ing
Self
Extinguishin
g
Self
Extinguishing
Oxygen Index LOI (%
O2)
40-45 30-35 >95 >95 >95
Heating Value
H0 MJ.kg-1
15 14 5 5 5
Thermal
Conductivity W.K-1.m-
1
0.17 0.24 0.26 0.21 0.26
Corrosive Gases In
Case Of Fire
Hydrofluoric Yes Yes Yes Yes
Radiation Resistance
max Mrad
10 10 1 0.1 0.1
Tensile Strength
N/mm2
50-80 40-50 15-25 25-30 80
Elongation At Break
%
150 150 250 250 50
Shore Hardness 75-80 (D) 70-75 (D) 55-60 (D) 55-60 (D) 55-60 (D)
Abrasion Resistance Very Good Very Good Very Good Very Good Very Good
Water Absorption % 0.01 0.02 0.01 0.01 0.01
Halogen Free No No No No No
Weather Resistance Very Good Very Good Very Good Very Good Very Good
Cold Resistance Very Good Very Good Very Good Very Good Very Good
Halogen Free CompoundsH HX
Not Cross
Linked
Cross Linked
Halogen Free
Polymer
Compounds
Halogen Free
Polymer
Compounds
Density g/cm3 1.4-1.6 1.4-1.6
Breakdown Voltage KV/mm
(20oC)
25 25
Specific Volume Resistivity Ω cm
(20oC)
1012-1014 1013-1014
Dielectric Constant 50 Hz (20oC) 3.4-5 3.4-5
Dielectric Loss Factor (tan δ) ~10-3 10-2-10-3
Working
Temperature
Permanent oC -30 +70 -30 +90
Short Time oC +100 +150
Melt Temperature +oC >130 -
Flame Resistance Self Extinguishing Self Extinguishing
Oxygen Index LOI (% O2) ≤40 ≤40
Heating Value H0 MJ.kg-1 17-22 16-25
Thermal Conductivity W.K-1.m-1 0.17 0.20
Corrosive Gases In Case Of Fire No No
Radiation Resistance max Mrad 100 200
Tensile Strength N/mm2 8-13 8-13
Elongation At Break % 150-250 150-250
Shore Hardness 65-95 (A) 65-95 (A)
Abrasion Resistance Medium Medium
Water Absorption % 0.2-1.5 0.2-1.5
Halogen Free Yes Yes
Weather Resistance Medium in Black:
Good
Medium in Black:
Good
Cold Resistance Average Average
- See more at: http://myelectrical.com/notes/entryid/178/cable-insulation-properties#sthash.uUKfqjdn.dpufnotes/entryid/182/cable-sizing-tool#sthash.AV
AtAKwn.dpuf
IEC 60287 Current Capacity of Cables - Rated Current By Steven McFadyen on February 18th, 2013
This note looks at the formulae used to calculate the rated current capacity of a cable in line with IEC
60287 "Calculation of the continuous current rating of cables (100% load factor)". Before you continue
reading this note, if you have not done so already we would suggest first reading our IEC 60287
introduction note:
IEC 60287 Current Capacity of Cables - An Introduction
In the previous note we looked at the approach taken by the standard to the sizing of cables and
illustrated this with an example. We then looked at one method of applying the standard and identified
resources enabling the calculation of all the various parameters involved. In the note we are going to put
everything together and reveal the necessary equations for actually calculating the cable maximum
current rating.
The image illustrates the thermal model for a cable.
Heat is generated within the cable by various mechanisms - conductor I2R loss, dielectric loss, sheath
loss, armour loss and direct solar radiation. Some or all of this heat is dissipated through the cable
insulation, bedding, serving and into the surrounding medium. The rate of heat flow is related to the
temperature difference across the cable and affected by the ambient temperature, temperature rises due
to other cables and any critical temperature rise of the soil above ambient.
In thermal equilibrium, when all these factors have balanced and the temperature of the conductor is the
maximum allowable for the insulation; we have the maximum rated current for the cable. It can probably
be appreciated by now, that in typical real life situations, this can be quite a complicated calculation.
Note: rated current capacity found by the method assumes that the cable is fully loaded for
100% of it's operation time. For cables which have varying or cyclic loads, the current
rating could possibly be increased.
Tip: the thermal model is worth remembering as enables us to intuitively understand how a
cable is likely to behave in conditions which are not normally encountered. For example, if
a cable is run along a refrigerated gas pipe, we can hazard that this will reduce the ΔΘ and
hence the cable will be able to carry more current.
Change in temperature across a material is equal to the heat input multiplied by the thermal resistance of
the material. In terms of the thermal model and for a simple a.c. cable, the heat balance equation is given
by (a list of symbols is given at the end of the note):
Within the standard this above is used to derive the equations for current rating. It is simplified for d.c.
cables by eliminating any a.c. only effects and modified for partial drying of soil and solar radiation where
appropriate.
Contents [hide]
1. Rated Current of Cables
2. List of Symbols
Rated Current of CablesThe standard gives the following equations for the calculation of the cable current rating (for all alternating
current voltages and direct current up to 5 kV):
Buried cables where drying out of the soil does not occur or cables in air
AC cables
DC cables
Buried cables where partial drying-out of the soil occurs
AC cables
I=[Δθ−Wd[0.5T1+n(T2+T3+vT4)]+(v−1)ΔθXR[T1+n(1+λ1)T2+n(1+λ1+λ2)(T3+vT4)]]0.5
DC cables
I=[Δθ+(v−1)ΔθXR′[T1+nT2+n(T3+vT4)]]0.5
Buried cables where drying-out of the soil is to be avoided
AC cables
I=[Δθx−nWdT4nRT4(1+λ1+λ2)]0.5
DC cables
Cables directly exposed to solar radiation
AC cables
DC cables
Note: when calculating a cable where some drying of the soil may occur, it is also
necessary to perform the calculation for no drying out of soil and take the worse case
(lower) rating.
The calculation of each element needs some explanation and these have been split across several notes
(with each note dealing with one topic). For details, please refer to the first note in this series, which
lists the other related notes.
List of Symbolsn - number of load carrying conductors
v - ratio of thermal resistivity of dry and moist soils
I - rated conductor current, A
R - a.c. resistance of the conductor per unit length, Ω/m
R' - d.c. resistance of the conductor per unit length, Ω/m
T1 - thermal resistance per core between conductor and sheath, K.m/W
T2 - thermal resistance between sheath and armour, K.m/W
T3 - thermal resistance of external serving, K.m/W
T4 - thermal resistance of surrounding medium, K.m/W
T4* - external thermal resistance (free air) adjusted for solar radiation, K.m/W
De* - cable diameter over insulation, m
H - intensity of solar radiation, W/m2
Wd - dielectric loss per units length, W/m
λ1 - ratio of losses in metal sheath to total losses in all conductors
λ2 - ratio of losses in armouring to total losses in all conductors
σ - absorption coefficient of solar radiation for cable surface
Θ - maximum conductor operating temperature, °C
Θa - ambient temperature, °C
ΔΘ - temperature difference (Θ-Θa), K
ΔΘx - critical temperature of soil, °C- See more at: http://myelectrical.com/notes/entryid/210/iec-60287-current-capacity-of-cables-capacity-equations#sthash.MOCOY4Hw.dpuf
By Jeson Pitt on August 12th, 2013
Power cables can basically be classified into earthed and unearthed cables, where earthed and
unearthed refer to the application for which the cable is used. Earthed system refers to a three phase
system whose star point is grounded directly and the voltage between the healthy phases and the ground
will be - 11kV/1.732 or 6.6/1.732. In the case of unearthed cable, ground voltage is equal to phase to
phase voltage.
Earthed Cables Unearthed Cables
Medium Voltage (MV) voltage power distribution system cables can be both earthed and unearthed. If the
system is earthed, then we use earthed rated cable for manufacturing; and if the system is unearthed, we
use an unearthed rated cable for manufacturing.
Compared with the earthed cable as per the manufacturer's specifications, the unearthed cable needs
higher insulation levels.
The greatest difference arises in the voltage grade (Uo/U), which is:
Earthed System Unearthed System
1.9/3.3 kV, 3.8/6.6 kV, 6.35/11 kV, 12.7/22
kV and 19/33 kV
3.3/3.3 kV and 11/11 kV
In an exception to the abover, the cables of 6.35/11kV for an earthed system can also be used in the
place of 6.6/6.6 kV for an unearthed system. This is because each core of the cable has the insulation
level to withstand 6.6kV due to which between core to core insulation level will be 6.6kV+6.6kV = 11kV.
Contents [hide]
1. The Difference in Origin
2. Insulation Strength
3. Cable Requirements
4. Preferable Cable for MV Transmission
The Difference in OriginThe first generators and transformers had small capacities in which the fault current was less and the star
point was solidly grounded due to which they were called earthed system. Generators that are now
available have 500MVA capacity and higher fault levels. So, if there is an earth fault, a heavy current
flows into the fault, which leads to the damage of the generators and transformers. In such a scenario, to
reduce the fault current, the star point is connected to the earth through a resistance. In case of an earth
fault in one phase, the voltage of the faulty phase with respect to the earth appears across the resistance.
Due to this, the voltage of the remaining two healthy phases with respect to the earth rises by 1.7 times. If
the insulation system is not designed to sustain these increased voltages, they are likely to develop earth
faults.
In case of earthed cable, three phase cables are earthed to a ground and each of the phase system is
grounded to the earth. While the unearthed system (if system neutral is not grounded) phase to ground
voltage can be equal to phase to phase voltage; in such situations the insulation level of the conductor to
the armor should be equal to the insulation level of conductor to conductor. In the three phase earthed
systems, phase to earth voltage is 1.732 times less than phase to phase voltage. Thus, the voltage stress
on the cable to armor is 1.732 times less than the voltage stress between conductor to conductor.
Insulation StrengthUnearthed cable requires more insulation strength than earthed cable. If a fault occurs in the phase to
ground voltage is √3 time the normal phase to ground voltage. So, if an earthed rated cable is used in an
unearthed system, it may result in an insulation puncture. Hence, it is essential to use unearthed rated
cable in such situations, especially in the case of 6.6kV systems where resistance type earthing is used.
Cable RequirementsCarrying forward the above point, 11kV earthed cable can be used in place of 6.6kV unearthed system
since the cable manufacturing process is the same. The size of the cable will depend on the current rating
and voltage level. So,
Voltage grade (Uo/U) where Uo is phase to earth voltage and U is phase to phase
voltage
Earthed system has an insulation grade of kV/1.75x kV
For earthed system (Uo/U): 1.9/3.3 kV, 3.8/6.6 kV, 6.35/11 kV, 12.7/22 kV and 19/33
kV
Unearthed system has insulation grade kV/kV
3 phase 3 wires system generally comes with unearthed grade cable and 3 phase 4
wire systems can be used as earthed grade cables
Preferable Cable for MV TransmissionFor MV transmission, earthed cable will be more economical, but unearthed cable offers more insulation.
This is because, if an earth fault occurs in the underground system, the voltage between the healthy
phases and the ground will be equal to phase to phase voltage - 11kV or 6.6kV and higher insulation level
is required. The voltage of the healthy phases rises by nearly 1.7 times resulting in an earth fault since the
insulation of these phases is not designed for increases voltage. It is advisable to opt for an unearthed
cable so that the core insulation has enough strength.
- See more at: http://myelectrical.com/notes/entryid/226/cables-for-mv-power-distribution-earthed-versus-unearthed-systems#sthash.BtDZJa5J.dpuf
By Steven McFadyen on November 12th, 2013
Cable cross section showing
insulation
Dielectrics (insulating materials for example) when subjected to a varying electric field, will have some energy loss. The varying electric field causes small realignment of weakly bonded molecules, which lead to the production of heat. The amount of loss increases as the voltage level is increased. For low voltage cables, the loss is usually insignificant and is generally ignored. For higher voltage cables, the loss and heat generated can become important and needs to be taken into consideration.
Dielectrics (insulating materials for example) when subjected to a varying electric field, will have some
energy loss. The varying electric field causes small realignment of weakly bonded molecules, which lead
to the production of heat. The amount of loss increases as the voltage level is increased. For low voltage
cables, the loss is usually insignificant and is generally ignored. For higher voltage cables, the loss and
heat generated can become important and needs to be taken into consideration.
Dielectric loss is measured using what is known as the loss tangent or tan delta (tan δ). In simple terms,
tan delta is the tangent of the angle between the alternating field vector and the loss component of the
material. The higher the value of tan δ the greater the dielectric loss will be. For a list of tan δ values
for different insulating material, please see the Cable Insulation Properties note.
Note: in d.c. cables with a static electric field, there is no dielectric loss. Hence the
consideration of dielectric loss only applies to a.c. cables.
Contents [hide]
1. Cable Voltage
2. Cable Dielectric Loss
3. Symbols
4. See Also
Cable VoltageDielectric loss only really become significant and needs to be taken into account at higher voltages. IEC
60287 "Electric Cables - Calculation of the current rating", suggests that dielectric loss need only be
considered for cables above the following voltage levels:
Cable Type U0,
kV
Butyl Rubber 18
EDR 63.5
Impregnated Paper (oil or gas filled) 63.5
Impregnated Paper (solid) 38
PE (high and low density) 127
PVC 6
XLPE (filled) 63.5
XLPE (unfilled) 27
Cable Dielectric LossCable Capacitance
Cable capacitance can be obtained from manufacturers or for circular conductors calculated
using the following:
C=ε18ln(Didc)10−9F.m−1
Given the tan δ and capacitance of the cable, the dielectric loss is easily calculated:
Wd=ωCU02tanδ
It is possible to use the above for other conductor shapes if the geometric mean is substituted
for Di and dc.
Symbolsdc - diameter of conductor, mm
Di - external diameter of insulation, mm
C - cable capacitance per unit length, F.m-1
U0 - cable rated voltage to earth, V
Wd - dielectric loss per unit length, W.m-1
tan δ - loss factor for insulation
ε - insulation relative permitivity
ω - angular frequency (2πf)
See Also- See more at: http://myelectrical.com/notes/entryid/241/dielectric-loss-in-cables#sthash.Nw6gAiWM.dpuf
Power Transformers - An Introduction By Steven McFadyen on November 29th, 2012
One of the fundamental requirements of an alternating current distribution systems it to have the ability to
change the magnitude of voltages. It is more efficient to transmit power at high voltages over long
distances, whereas it is safer and more practical to use a low voltage to drive appliances and equipment.
Transformers are used to achieve this.
Contents [hide]
1. General Theory
1. Three Phase Transformers
2. Practical Aspects
1. Vector Group
2. Transformer Tapping
3. Temperature Derating
4. Altitude Derating
3. References
General TheoryA transformer is a device consisting of two (or more) windings coupled together magnetically. A changing
current in one winding (normally called the primary), will generate a magnetic field. This magnetic field
links with the second winding (normally called the secondary) and will induce a current into this winding.
Transformer operation principal
The illustration shows how a voltage V1 applied to the primary winding of N1 turns, creates a current
I1 which causes the generation of the magnetic flux in the core. The flux in the core with generates
voltage V2 in the secondary winding of N2 turns, giving a current I2 in the load.
Core - to facilitate distribution of the magnet field, transformer cores are usually made of
steel laminations. Laminations are preferable to a solid steel cores as they reduce losses.
The relationship between voltage, number of turns and current is given by:
and
Tip - transformer efficiencies are high and by assuming the input power equals the output
power the above voltage and current relationships are easily derived: input power (in VA) =
V1 x I1 with equals the output power = V2 x I2, which rearranged give the above.
Transformers are not perfect and there are losses. This can be divided into two types:
1. I2R losses - in the windings occur due to resistive losses in both the primary and
secondary windings. Resistive losses increase with load magnitude.
2. Core losses - result from eddy current and hysteresis losses in within the transformer
core. Losses in the core are fairly constant regardless of loading.
The total loss is the sum of the core losses Pc and the resistive losses due to primary current I1, primary
winding resistance R1, secondary current I2 and secondary winding resistance R2:
The efficiency of the transformer can be expressed as:
Three Phase Transformers
Transformer operation principal Three phase transformers can be made by combining single phase transformers. One of the more common implementations is to construct a core of three limbs closed at the top and bottom. Each individual cores contains the primary and secondary winding of a single phase.
Windings may be connected either in star or delta depending on requirements. The image shows one
start connected and one delta connected winding.
Practical Aspects
Vector GroupTransformers can be wound in various configurations (delta-star, star-star, etc.). Depending on the
configuration there will be a phase shift between the primary and secondary of the transformer. The
transformer configuration and phase shift is termed the vector group.
The vector group is represented by a capital letter for the primary winding, a lower case letter for the
secondary winding and followed by a number (1 to 11). The letter indicated the winding arrangement -
D=Delta, Y=Star and Z=Zigzag. The number is the phase shift in multiples of 30 degrees. For example:
Dy11 - delta connected primary, star secondary, 330° (-30°) phase shift
Dd0 - delta connected primary, delta secondary, no phase lag
Sometimes a third letter is added to indicated the neutral is brought out, for example Dyn11 (delta-star
transformer with the secondary neutral brought out).
Transformer Tapping
Three phase transformer (core type winding) The nominal voltage of a transformer is related to the turns ration between the primary and secondary. In use the primary voltage can vary and the secondary current can vary. Both these will affect the output voltage of the transformer.
To cater for varying primary and secondary conditions, transformers are often fitted with taps on one of
the windings; so that the turns ratio can be adjusted somewhat. These are often expressed as numbers.
For example, a low voltage transformer may have -5%, -2.5%, 0%, +2.5% and +5% taps. At 0% tap the
transformer will be operating at its designed turns. At +2.5% the transformer secondary voltage will be
2.5% larger than what it would be if set at 0% (for the same primary voltage and secondary current).
An example of use would be setting a +2.5% or +5% tap on a transformer which is heavily loaded to help
compensate for the voltage drop in the cables.
Temperature DeratingAccording to the standards[1][ 2][3], transformers are designed for:
a maximum temperature - 40 °C
30 °C monthly average of the hottest month
20 °C yearly average
outdoor transformer minimum temperature -25 °C
indoor transformer minimum temperature -5 °C
When the transformer is designed for service where the temperature of the cooling air exceeds the
maximum allowable, the temperature rise limits shall be reduced by the amount of the excess.
Alternatively the temperature differences can be taken into account by adjusting the transformer capacity:
A
m
b
i
e
n
t
t
e
m
p
e
r
a
t
u
r
e
(
a
n
n
u
a
l
a
v
e
r
a
g
e
)
C
a
p
a
c
i
t
y
-
2
0
°
C
1
2
4
%
-
1
0
°
C
1
1
8
%
0
°
C
1
1
2
%
+
1
0
°
C
1
0
6
%
+
2
0
°
C
1
0
0
%
+
3
0
°
C
9
3
%
Altitude Derating
Transformers are designed for an altitude of 100 m above sea level. For other altitudes, the limit of the
average winding temperature rise shall be reduced by[2][3]:
oil immersed, air naturally cooled - 1 K for every 400 m above design altitude
oil immersed force cooled - 1 K for every 200 m above design altitude
oil immersed water cooled - no correction for altitude
dry-type air naturally cooled - 2.5% for every 500 m above design altitude
dry-type air force cooled - 5% for every 500 m above design altitude
References- See more at: http://myelectrical.com/notes/entryid/199/power-transformers-an-introduction#sthash.QDcO9HVU.dpuf
By Steven McFadyen on July 5th, 2011
While there are a vast array of cable insulation materials, these are often divided into two general types; Thermoplastic or Thermosetting. For example the current capacity determination of a cable in accordance with the UK Wiring Regulations is categorized into thermoplastic and thermosetting cables.
Thermoplastic materials are composed of chains of molecules (polyethylene for
example). When heat is applied the energy will allow the bonds to separate and the
material can flow (melt) and be reformed.
Thermosetting materials are formed when materials such as polyethylene undergo
specific heating or chemical processes. During this process the individual chains become
cross linked by smaller molecules making a rigid structure. Thermosetting materials
cannot reheated, melted and remolded.
While thermoplastic materials have the advantage of being able to be reformed, thermosetting materials
are generally more heat resistance and have greater strength.
The operating temperature of any cable is an important parameter in determining the maximum allowable
current. While the actual temperature varies depending on the material used, the UK Wiring Regulations
limits the choice in calculating the current rating to two temperatures only:
Thermplastic 70 0C
Thermosetting 90 oC
Note: more specific calculations based on actual material properties are allowed. However, for ease of
use most practical application will use 70 oC or 90 oC and the methods outlined in the regulations.
See Also
- See more at: http://myelectrical.com/notes/entryid/72/thermoplastic-and-thermosetting#sthash.5RvpSHhI.dpuf\
Cable Sizing Tool
By Steven McFadyen on May 20th, 2012
Our cable sizing tool is one of the more popular tools on the site. The tool enables cables to be sized in compliance with BS 7671 (the IEE Wiring Regulations) and by implication IEC 60364.
This post gives some insight into how the tool works, the
calculations carried out and how to use it. With the tool being based
on BS 7671, this post will also provide an introduction and
explanation of the cable sizing method given in the standard.
The sizing tool can be found at:
myElectrical Cable Sizing Tool
Contents [hide]
1. The Procedure
2. The Formulae
1. Current Capacity
2. Voltage Drop
3. Fault Levels
3. Frequently Asked Questions
The ProcedureThe flowchart (click for a larger image) shows the general procedure followed by the tool:
current capacity – a cable size is found which is adequate for the expected current
voltage drop – the voltage drop on the selected cable is checked and if to big the cable
size is increased
fault level – the fault level withstand is checked and if not adequate the cable size is
increase
Any errors or warnings generated during the calculation are passed on the the user.
In addition to cable size the tool also calculates the cable impedance and fault levels at the load end of
the cable.
The FormulaeThe calculation method follows the procedures given in BS 7671:2008 (the IEE Wiring Regulations), 17th
Edition.
Definitions:
Iz - current carrying capacity of the cable (continuous service under defined installation
conditions)
It - tabulated value of current (for the type of cable, type of installation, and at an ambient of
30oC)
Ib - design current of the circuit (expected in normal service)
In - nominal setting of any protective device
I2 – operating current of the protective device
Ca - correction factor for the ambient temperature
Cc - correction factor for the type of protective device used
Cg - correction factor for grouping of circuits/cables
Ci - correction factor thermal insulation
Ct - correction factor for the operating temperature of the conductor
Np - number of cables in parallel
tp - maximum permitted operating temperature
Current CapacityBy considering any correction factors, the tabled current for a cable installed in a given situation can be
found. Once the tabled value of current is found, the cable size is determined by selecting the next
largest cross sectional area in the lookup tables.
For single circuits:
For groups where simultaneous overload is possible:
For groups not liable to simultaneous overload (the maximum of):
For cables where overload protection is not required:
Once It is known, this size of cable is then looked up in the current carrying capacity tables:
Tables 4D1A to 4J4A (pages274 to 316) – current carrying capacity
Correction factors are obtained from the following tables (dependant upon cable type and installation):
Table 4B1 – rating factors for cables in air, ambient other than 30 °C
Table 4B2 – rating factors for buried cables, ambient other than 20 °C
Table 4B3 – rating factors for buried cables, thermal resistivities other an 2.5 K.m.W-1
Table 4C1 to 4C3 – rating for grouping of circuits/cables
Table 52.2 – rating factors for cables surrounded by thermal insulation
Voltage DropVoltage drop calculations consider both the power factor of the system and a correction factor for the
cable operating standard. Tables 4D1B to 4J4B of the standard give voltage drops (resistive and
reactive) in (mV/A/m), which is equivalent to mΩ/m (or Ω/m if adjusted).
By looking up in these tables and using the cable length, the sizing tool determines the resistance, R and
reactance, X of the cable. The calculated voltage drop, is then given by:
The temperature correction factor is only applied to the resistance and is given by:
Note: the tool carries out all calculations in complex form.
Fault LevelsThe fault withstand rating of the cable is determined using the adiabatic equation:
Where:
S is the cable cross sectional area in mm2
I is the fault current which can flow in A
t is the operating time of the protective device in S
k is a factor related to the conductor material and insulation – tables 54.2 to 54.6 of the
standard
Frequently Asked QuestionsHow does the tool taking into account parallel conductors?
Additional parallel cables are automatically added to group derating (you don't need to increase this
manually).
You can click the ignore checkbox to change this (for example if your cables are more than two diameters
apart).: code changes have been made. The updated version of the calculator is now live.
What exactly is the No.Circuits/Cables?
Group derating takes into account heat generated by adjacent cables. Each circuit is usually supplied by
one cable and the number of circuits will equal the number of cables. Sometimes several cables are run
a parallel for a single circuit and this will increase the total number of cables (and group derating).
Tip: if cables are spaced more than twice their overall diameter apart, then no group derating is required.- See more at: http://myelectrical.com/notes/entryid/182/cable-sizing-tool#sthash.kNNQ5pcU.dpuf
Harmonised Cable Codes and Colours By Steven McFadyen on August 28th, 2013
Within Europe the European Committee for Electrotechnical Standardization (CENELEC) has
standardised the both the designation and colour of cables. These are published in CENELEC document
HD 361 S3:1999 "System for cable designation" and HD 308 S2: 2001
"Identification of cores in cables and flexible cords". This note provides a general overview to the
harmonised system and gives some examples.
Contents [hide]
1. Cable Designation
1. Designation Codes
2. Cable Code Examples
2. Cable Colour Codes
Cable DesignationThe HD 261 document, classifies the construction of the cable by allocating codes (letters or numbers) to
represent the cable voltage, insulation material\, structural elements, sheath, special features and
conductor type.
For a full list of codes and their meanings, it is best to refer to the standard. A typical cable specification
would take the form of:
Laying out the Harmonised Cable Code
The layout of the cable code can be split into three parts. Fist the standard and nominal voltage are
given. This is followed by the insulation material, construction features and sheath. Finally the cores and
cross section are specified.
Each cable element is designated with a alpha numeric code as detailed in the tables below. Typically
these are connected together to form the final cable designation. Optional codes or codes that have no
relevance to the cable under consideration are simply omitted.
Note: some codes are preceded by a '-' sign, for example -A (aluminium).
Designation Codes
Identification of Designation
A authorised national standard
H harmonised standard
Nominal Voltage
01 100 V
03 300/300 V
05 300/500 V
07 450/750 V
Structural Elements
- Concentric Conductors
A Concentric aluminium conductor
A6 Concentric aluminium conductor,
meander-shaped
Insulation & Sheath Materials
B Ethylene-propylene rubber (EDR)
+90°C
B2 Ethylene-propylene rubber (EDR),
hardened
B3 Butyl rubber
E Polyethylene
E2 Polyethylene, high density
E4 Poly-tetrafluorethylene
E5 Eethylene propylene rubber
E6 Ethylene tetrafluorethylene
E7 Polypropylene
G Ethylene-vinylacetate (EVA)
J Glass fibre braiding
J2 Glass fibre wrapping
C Concentric copper-conductor
C6 Concentric copper-conductor, meander-
shaped
C9 Divided concentric copper conductor
- Screen
A7 Aluminium screen
A8 Aluminium screen, individual
conductors
C4 Copper braid screen
C5 Copper braid screen, individual
conductors
C7 Copper tape screen
C8 Copper tape screen, individual
conductors
D Screen of one or more thin steel tapes
- Armouring
Z2 Armouring of round steel wires
Z3 Armouring of flat steel wires
Z4 Armouring of steel tape
Z5 Braiding of steel wires
Z6 Supporting braid of steel wires
Z7 Armouring of sectional steel wires
Y2 Armouring of round aluminium wires
Y3 Armouring of flat aluminium wires
Y5 Armouring of special materials
Y6 Armouring of steel wires and/or tape
and copper wires
Conductor Material
w/o designation Copper
- A Aluminium
- Z Special material and/or special shape
Special Design Features
- Supporting Structures
D2 Textile or steel wires over cable
conductor
D3 Textile elements stranded in conductor
cable
D4 Self-supporting cables and wires
D5 Central conductor element
M Mineral insulation
N Chloroprene rubber (CR)
N2 Chloroprene-rubber (CR), welding
cable
N4 Chlorinated polyethylene
N5 Nitril-rubber
N6 Fluorinated rubber
N7 PVC nitril rubber compound
N8 Polychloroprene rubber, water
resistant
P Impregnated paper insulation
Q Polyurethane (PUR)
Q2 Polyethyleneterephthalate
Q3 Polystyrole
Q4 Polyamide
Q5 Polyamide
Q6 Polyvinylidene fluoride
R (NR, SR) natural or synthetic rubber
S (SIR) silicone rubber
T Textile braiding
T2 Textile braiding with flame retardant
T3 Textile conductor wrapping or tape
T4 Textile conductor wrapping or tape,
flame retardant
T5 Corrosion protection
T6 Textile braiding over individual
conductor or cable
V PVC
V2 PVC soft, resistant to increased
temperature, +90°C
V3 PVC soft, for low temperatures
V4 PVC soft, cross-linked
V5 PVC soft, oil resistant
X Cross-linked polyethylene
Z Cross-linked compound, LSZH
Z1 Thermoplastic compound, LSZH
Note: for details in insulation properties,
please refer to:
- Cable Insulation Properties
- Special Versions
w/o designation round cable construction
H Flat type as separable cables with or
without jacket
H2 Flat type of cables not separable
H3 Building Cable, flat webbed
H4 Multi conductor flat cable with one plain
conductor
H5 Two or more single conductor stranded,
non-jacket
H6 Flat cables with 3 or more conductors
H7 Cable with two-jacket extruded
insulation
H8 Coiled conductor
Conductor Type
- D fine wire stranded for welding cables
- E extra fine wire stranded for welding
cables
- F fine wire stranded for flexible cables
- H extra fine wire stranded for flexible
cables
- K fine wire stranded conductor for fixed
installation
- M Milliken conductor
- R conductor of multi stranded wires
- S sector-shaped conductor of multi
stranded wires
- U round conductor of single wire
- W sector-shaped conductor of single wire
- Y tinsel conductor
- Z conductor of special material
Protective Core
G with green/yellow earth conductor
X without earth conductor
Cable Code ExamplesDifferent manufacturers vary the way in which they present the harmonized designation for their cables.
Here are a few examples of varying cable designations:
H05VV5-F 2G075 is 00/500 V, PVC insulated, PVC sheathed, stranded flexible
conductor, 2 core 2.5 mm2 with protective conductor
H05V-K 1X1 is 300/500 V, PVC insulated, fine wire stranded, single core 1 mm2 with
no protective conductor
S03VV-F 3G0.75 is national standard (VDE in this case), 300/300 V, PVC insulated, PVC
sheathed, fine wire stranded flexible cable, 3 core 0.75 mm2 with protective conductor
H07RV-F 3X10 is 450/750 V, natural rubber insulation, PVC sheath, fine wire stranded,
three core 10 mm2 with no protective conductor
H05Z-K 1X2.5 is 300/500 V, XLPE LSZH, fine wire stranded, single core 2.5 mm2
without protective conductor
Cable Colour CodesCENELEC (including BS 7671 - IEE Wiring Regulations)
Function Alpha-
numeri
c
Colour
Protective conductors Green and yellow
Functional earthing conductor Cream
a.c. power circuit
Phase of single-phase circuit L Brown
Neutral of single- or three-phase circuit N Blue
Phase 1 of three-phase a.c. circuit L1 Brown
Phase 2 of three-phase a.c. circuit L2 Black
Phase 3 of three-phase a.c. circuit L3 Grey
Two-wire unearthed d.c. power circuit
Positive of two-wire circuit L+ Brown
Negative of two-wire circuit L- Grey
Two-wire earthed d.c. power circuit
Positive (of negative earthed) circuit L+ Brown
Negative (of negative earthed) circuit M Blue
Positive (of positive earthed) circuit M Blue
Negative (of positive earthed) circuit L- Grey
Three-wire d.c. power circuit
Outer positive of two-wire circuit derived from
three-wire system
L+ Brown
Outer negative of two-wire circuit derived
from three-wire system
L- Grey
Positive of three-wire circuit L+ Brown
Mid-wire of three-wire circuit M Blue
Negative of three-wire circuit L- Grey
Control circuits, ELV and other
applications
Phase conductor L Brown, Black, Red, Orange,
Yellow, Violet, Grey, White, Pink or
Turquoise
Neutral or mid-wire N or M Blue
If anyone notices any mistakes or corrections which are needed, please leave a comment below.
- See more at: http://myelectrical.com/notes/entryid/228/harmonised-cable-codes-and-colours#sthash.TVhNjX5H.dpuf
By Steven McFadyen on May 10th, 2012
Everything physical in electrical engineering from insulations to conductors revolves around materials. Here we are listing common materials along with their most useful properties in relation to electrical engineering.
Contents [hide]
1. The Table of Resistivities
2. The Properties Tables
1. Properties of Non Metallic Solids (at 293 k)
2. Properties of Metallic Solids (at 293 K)
3. Properties of Gasses
4. Properties of Liquids (at 293 K)
5. Properties of Semiconductors
6. Properties of Commercial Permanent Magnetic Materials
The Table of ResistivitiesThis table shows the resistivity and temperature coefficient of various materials at 20°C (68 °F)
Material Resistivity (Ω-m) at 20 °C Coefficient*
Silver 1.59×10-8 0.0038
Copper 1.72×10-8 0.0039
Gold 2.44×10-8 0.0034
Aluminium 2.82×10-8 0.0039
Calcium 3.3x10-8 ?
Tungsten 5.60×10-8 0.0045
Nickel 6.99×10-8 ?
Iron 1.0×10-7 0.005
Tin 1.09×10-7 0.0045
Platinum 1.1×10-7 0.00392
Lead 2.2×10-7 0.0039
Manganin 4.82×10-7 0.000002
Constantan 4.9×10-7 0.00001
Mercury 9.8×10-7 0.0009
Nichrome 1.10×10-6 0.0004
Carbon 3.5×10-5 -0.0005
Germanium 4.6×10-1 -0.048
Silicon 6.40×102 -0.075
Glass 1010 to 1014 ?
Hard rubber approx. 1013 ?
Sulfur 1015 ?
Paraffin 1017 ?
Quartz (fused) 7.5×1017 ?
PET 1020 ?
Teflon 1022 to 1024 ?
* the numbers in this column increase or decrease the significant portion of the resistivity. For example, at
30°C (303.15 K), the resistivity of silver is 1.65×10-8. This is calculated as Δρ = α ΔT ρo where ρo is the
resistivity at 20°C and α is the temperature coefficient .
The Properties Tables
Properties of Non Metallic Solids (at 293 k)
ρ' Tm λ εr
Legend: ρ' = Density, kg m-3 Tm = Melting point, K λ = Thermal conductivity, W m-1K-1 εr = Relative permittivities at 293 K
Alumina,ceramic 38002300
29 -
Amber - - - 2.8
Bone 1850- - -
Brick,building 2300- 0.6 -
Brick,fireclay 2100- 0.8 -
Brick,paving 2500- - -
Brick,silica 1750- 0.8 -
Carbon,graphite 23003800
5 -
Carbon,diamond 3300- 900 -
Concrete 2400- 0.1 -
Cork 240 - 0.05-
Cotton 1500- - -
Ebonite - - - 2.7-2.9
Epoxy resin 1120- - -
Fluon (PTFE) 2200- 0.25-
Glass,crown 26001400
1 5-10
Glass,flint 42001500
0.8 5-10
Glass wool 501400
0.045-10
Ice 920 273 2 75
Kapok 50 - 0.03-
Magnesium oxide 36003200
- -
Marble 2600- 2.9 8.5
Melamine formaldehyde 1500- 0.3 -
Mica - - - 5.7-6.7
Naphthalene 1150350 0.4 -
Nylon 1150470 0.25-
Paraffin wax 900 330 0.252-2.3
Perspex 1190350 0.2 3.5
Phenol formaldehyde 1300- 0.2 -
Polyethylene,low density 920 410 - -
Polyethylene,high density 955 410 - -
Polypropylene 900 450 - -
Polystyrene 1050510 0.082.55
Polyvinylchloride (PVC),non-rigid1250485 - 4.5
Polyvinylchloride (PVC),rigid 1700485 - 4.5
Polyvinylidine chloride - 470 - -
Quartz fibre 26602020
9.2 -
Rubber (polyisoprene) 910 300 0.15-
Silicon carbide 3170- - -
Sulphur 2070386 0.263.6-4.3
Teflon - - - 2.1
Titanium carbide 4500- 28 -
Wood,oak (with grain) 650 - 0.15-
Wood,Spruce (with grain) 600 - - -
Wood,Spruce (across grain) - - - -
Properties of Metallic Solids (at 293 K)
ρ' Tm λρ x10-
8 α20 x10-
4
Legend: ρ = Density, kg m-3 Tm = Melting point, K λ = Thermal conductivity, W m-1 K-1 ρ = Electrical Resistivity, Ω m α20 = Temperature coefficient of resistance, K-
1
Aluminium 2710 932 2012.65 40
Aluminium, strong alloy 2800 800 1805 16
Antimony 6680 904 18 40 50
Bismuth 9800 544 8 115 45
Brass (70Cu/30Zn) 8500 13001108 15
Bronze (90Cu/10Sn) 8800 130018030 -
Cobalt 8900 176569 6 66
Constantan 8880 136023 47 0.4
Copper 8930 13563851.7 39
German silver (60Cu/25Zn/15Ni)8700 130029 33 4
Gold19300
13402962.4 34
Invar (64Fe/36Ni) 8000 180016 81 20
Iron, pure 8780 181080 10 65
Iron, cast grey 7150 150075 10 -
Iron, cast white 7700 142075 10 -
Iron, wrought 7850 181060 14 60
Lead11340
600 35 21 43
Magnesium 1740 924 1504 43
Manganin 8500 - 22 45 0.1
Monel (70Ni/30Cu) 8800 160021042 20
Nickel 8900 172659 59 60
Nickel, strong alloy 8500 1320- - -
Phosphor bronze - - - 7 60
Platinum21450
204269 11 38
Silver10500
12304191.6 40
Sodium 970 371 1344.5 44
Solder, soft (50Pb/50Sn) 9000 490 - - -
Stainless Steel (18Cr/8Ni) 7930 180015096 6
Steel, mild 7860 170063 15 50
Steel, piano wire 7800 170050 - -
Tin 7300 505 65 11 50
Titanium 4540 195023 53 38
Zinc 7140 693 1115.9 40
Properties of Gasses
ρ' Tb λ εr
Legend: ρ' = Density, kg m-3 Tb = Boiling point, K λ = Thermal conductivity, W m-1K-
1 εr = Relative permittivities at 293K
Acetylene (C2H2)1.173
189 0.0184-
Air1.293
83 0.02411.000536
Ammonia (NH3)0.771
240 0.0218-
Argon (Ar)1.784
87 0.01621.000545
Carbon dioxide (CO2)1.977
195 0.01451.000986
Carbon monoxide (CO) 1.25 81 0.02321.0007
Chlorine (Cl2)3.124
238 0.0072-
Cyanogen (C2N2)2.337
252 - -
Deuterium - - - 1.00027
Ethylene (C2H4) 1.26 170 0.0164-
Helium (He)0.179
4.25 0.14151.00007
Hydrogen (H2) 0.09 20.350.16841.00027
Hydrogen Chloride (HCl) 1.64 189 - -
Hydrogen sulphide (H2S)1.538
211 0.012 -
Methane (CH4)0.717
109 0.0302-
Neon - - - 1.000127
Nitric oxide (NO) 1.34 121 0.0238-
Nitrogen (N2) 1.25 77 0.02431.00058
Nitrous oxide (N2O)1.978
183 0.0151-
Oxygen (O2)1.428
90 0.02441.00053
Sulphur dioxide (SO2)2.927
263 0.00771.00082
Water vapour (273 K H2O)0.8 - 0.01581.0006
Properties of Liquids (at 293 K)
ρ' Tm Tb λ εr
Legend: ρ’ = Density, kg m-3 Tm = Melting point, K Tb = Boiling point, K λ = Thermal conductivity, W m-1K-
1 εr = Relative permittivities at 293K
Acetic acid (C2H4O2) 1049 2903910.18 -
Acetone (C3H6O) 780 1783300.16121.3
Benzene (C6H6) 879 2793530.14 2.28
Bromine (Br) 3100 266332- -
Carbon disulphide (CS2) 1293 1623190.144-
Carbon tetrachloride (CCl4)1632 2503500.1032.17
Chloroform (CHCL3) 1490 2103340.121-
Caster oil - - - - 4.5
Ether,diethyl (C4H10O) 714 1573080.1274.34
Ethyl alcohol (C2H6O) 489 1563520.17724.7
Glycerine - - - - 43
Glycerol (C3H8O3) 1262 2935630.27 -
Mercury (Hg)13546
2346307.96 -
Methyl alcohol (CH4O) 791 1793370.201-
Nitrobenzene (C6H5NO2) 1175 2794840.16 35.7
Olive oil 920 - 5700.17 -
Paraffin,medical - - - - 2.2
Paraffin oil 800 - - 0.15 -
Pentane - - - - 1.83
Phenol (C6H60) 1073 314455- -
Silicon oil - - - - 2.2
Toluene (C7H8) 867 1783840.134-
Turpentine 870 2634290.1362.23
Water (H2O) 998 2733730.59180.37
Water,sea 1025 264377- -
Properties of Semiconductors Germanium Silicon
Crystal Structure diamond diamond
Bonding covalent covalent
Lattice constant 5.6575 5.4307
Atomic volume, m3 kg-1 mol-1 13.5x10-3 12.0x10-3
Density, kg m-3 5.32x103 2.33x103
Cohesive energy, J kg-1 mol-1 3.72x108 4.39x108
Melting point, oC 958.5 1412
Mobility, m2 V-1 s-1electrons 0.38 holes 0.18
electrons 0.19 holes 0.05
Energy gap, eV (at 20 oC) 0.67 1.107
Density of states effective masselectrons 0.35 me holes 0.56 me
electrons 0.58 me holes 1.06 me
a, mm mK-1 5.75 7.6
Properties of Commercial Permanent Magnetic Materials Composition RemananceCoercivityBxH
Al Ni CoCuNbBr, TBHC A m-3
(BH)max J m-
3 Remarks
Alnico IV H 1226 8 2 - 0.6 63000 10x103 isotropic
Ticonal C 8 13.5243 0.61.26 52000 430 isotropic
Column 8 13.5243 0.51.35 64000 64 columnar
Pt-Co alloy - - 23- - 0.45 210000 300 ductile
Barium Ferrite - - - - - 0.2 135000 7550 isotropic
(BaO6Fe2O3Co5Sm) - - - - - 0.85 600000 140000
Elongated single domain magnet (Fe50%Co50%)
- - - - - 0.905 80000 40 mechanically weak
If you notice any errors or omissions in the tables, please add a comment below.
- See more at: http://myelectrical.com/notes/entryid/177/material-properties#sthash.28vhxKzP.dpuf
Introduction to Cathodic Protection By Steven McFadyen on April 25th, 2013
Sacrificial aluminium anodes on a ship Image Source: Cathodic Marine Engineering If two dissimilar metals are touching and an external conducting path exists, corrosion of one the metals can take place. Moisture or other materials acting as an electrolyte between the metals create an electrochemical cells (similar to that of a battery). Depending on the metals, one will act as a cathode and one as an anode of the cell.
Under this arrangement, stray d.c. currents will flow. In the same was a a normal cell, an electrochemical
reaction takes place and there is a resulting corrosion of the anode.
In practice, while it could be two dissimilar metals (steel aluminium for example), corrosion
could also be a result of microscopic differences in composition of the surface of a single
metal.
Cathodic protection works be converting all anodes which are likely to corrode the cathodes. There are
two principle methods of doing this:
1. attaching a more active metal to form a new anode (making the existing anode the
cathode) - resulting in the new material (sacrificial anode) being corroded rather than
the protected material
2. injection of a a d.c. current (impressed current) uses an anode connected to an
external d.c. source to provide the protection
History: it was the English Chemist, Sir Humphrey Davis (1778-1829), who first proposed
the concepts of cathodic protection. The first application was to protect the copper plating
of British naval ships in 1824[1].
Contents [hide]
1. Sacrificial Anode
2. Impressed DC Current
3. Cathode and Anodes
4. References:
Sacrificial AnodeThis is the practice of using a more active metal (sacrificial anode) connected to a structure to be
protected, knowing that this metal will be corroded. One example of this would be the use of aluminium
sacrificial anodes to protect steel structures in seawater.
Sacrificial anodes need to be electrically connected to the structure being protected.
Note: galvanised steel cable trays and trunking are commonly used. Here a sacrificial
coating of zinc is applied which acts acts the anode, preventing corrosion.
Impressed DC Current
Principle of ICCP Impressed current cathodic protection (ICCP) forces the structure to be protected to become the cathode by connection to an anode and injection of a direct current. The d.c. power supplies typically vary the current to achieve a required protection potential.
In ICCP systems, anodes can range from low end consumable metals to more exotic materials which will
exhibit little or no corrosion.
Cathode and AnodesWhen two metals are connected, determination of which will be the cathode and anode is made by
looking at the relative galvanic potentials of each material. Of the two materials, the metal with the lowest
potential will be the anode.
When measuring metals to find their galvanic potential each needs to be measured against a common
common cathode (hence the term "Anodic Index" is often used). The following table shows typical
galvanic potential of several metals as measured using a gold anode.
If measured against a different cathode, while the values of the galvanic potentials would be
different, it is the relative difference in potential between the two metals under
consideration in any situation which is important.
Metal Potential
Gold 0.00 (most cathodic)
Rhodium -0.05
Silver -0.15
Nickel -0.30
Copper -0.35
Brass & bronzes -0.40 to -0.45
Stainless Steels -0.50
Chromium Plated -0.60
Tin -0.65
Lead -0.70
Aluminium (wrought) -0.75 to -0.90
Iron, wrought -0.85
Aluminium (cast) -0.95
Zinc -1.20 to -1.25
Magnesium -1.75
Beryllium -1.85 (most anodic)
The amount of potential difference required between metals for corrosion to occur varies and is defendant
on the environment. As a rule of thumb, many people take an 0.25 V difference of normal environments,
0.5 V where the humidity (and temperature) are controlled and 0.15 V for more harsh industrial
environments[1].
As an example of using the table, we can see the potential difference between copper and aluminium is of
the order 0.6 V, giving a combination which is to be particularly avoided. In practice special bi-metalic
connections need to be employed whenever aluminium conductors are to be connected to copper
conductors.
References: [1] Cathodic Protection, Wikipedia
http://en.wikipedia.org/wiki/Cathodic_protection - accessed February 2013- See more at: http://myelectrical.com/notes/entryid/219/introduction-to-cathodic-protection#sthash.tansAAUQ.dpuf
Motor Efficiency Classification By Steven McFadyen on March 28th, 2012
Electric motors are one of the most widely used items of electrical equipment. Improving motor efficiency
benefits include, reduced power demand, lower operating costs and reduced environment impact.
In recognising the impact of motors on both power generation requirements and environmental issues,
regulation in many countries now dictate efficiency limits. When specifying motors, both designers and
purchasers should be concerned with efficiency performance.
Within the note, we look at both the European Efficiency Classification and IEC 60034 Efficiency Limits.
At the end we give some guidance on how to calculate the cost savings associated with the user of higher
efficiency motors.
Contents [hide]
1. European Efficiency Classification
1. How it works
2. Efficiency values
2. IEC 60034 Efficiency Limits
3. Calculation of cost savings
European Efficiency Classification
European Efficiency Classification The European Scheme to designate energy efficiency classes for low voltage AC motors has been in operation since 1999. The scheme established through co-opera ton between CEMEP and the European Commission is an important element of the European efforts to improve energy efficiency and thus reduce CO2 emissions.
How it worksMotors are defined by levels of efficiency per kW rating and the number of poles. The efficiency is
expressed at both full load and 3/4 load and labels must appear on the motor.
Motors included in the scheme are defined as totally enclosed fan ventilated (normally IP 54 or IP 55),
three phase AC, squirrel cage [[induction motor|induction motors]] in the range of 1.1 to 90 kW, rated for
400 V, 50 Hz, S1 duty class standard design.
Efficiency valuesFor motors designed 380 to 400 V with efficiency values based on 400 V.
2 pole motor specified efficiencies (%)
kW EFF1 EFF2 EFF3
1.1 >= 82.8 >= 76.2 < 76.2
1.5 >= 84.1 >= 78.5 < 78.5
2.2 >= 85.6 >= 81 < 81
3 >= 86.7 >= 82.6 < 82.6
4 pole motor specified efficiencies (%)
kW EFF1 EFF2 EFF3
>= 1.1 83.8 >= 76.2 < 76.2
>= 1.5 85 >= 78.5 < 78.5
>= 2.2 86.4 >= 81 < 81
>= 3 87.4 >= 82.6 < 82.6
4 >= 87.6 >= 84.2 < 84.2
5.5 >= 88.6 >= 85.7 < 85.7
7.5 >= 89.5 >= 87 < 87
11 >= 90.5 >= 88.4 < 88.4
15 >= 91.3 >= 89.4 < 89.4
18.5 >= 91.8 >= 90 < 90
22 >= 92.2 >= 90.5 < 90.5
30 >= 92.9 >= 91.4 < 91.4
37 >= 93.3 >= 92 < 92
45 >= 93.7 >= 92.5 < 92.5
55 >= 94 >= 93 < 93
75 >= 94.6 >= 93.6 < 93.6
90 >= 95 >= 93.9 < 93.9
>= 4 88.3 >= 84.2 < 84.2
>= 5.5 89.2 >= 85.7 < 85.7
>= 7.5 90.1 >= 87 < 87
>= 11 91 >= 88.4 <8 8.4
>= 15 91.8 >= 89.4 < 89.4
>= 18.5 92.2 >= 90 < 90
>= 22 92.6 >= 90.5 < 90.5
>= 30 93.2 >= 91.4 < 91.4
>= 37 93.6 >= 92 < 92
>= 45 93.9 >= 92.5 < 92.5
>= 55 94.2 >= 93 < 93
>= 75 94.7 >= 93.6 < 93.6
>= 90 95 >=9 3.9 < 93.9
IEC 60034 Efficiency Limits
IEC 60034 Efficiency Limits IEC 60034-30 defines three efficiency classes for of single speed, three phase, cage induction motors.
IE1 - Standard efficiency (efficiency levels roughly equivalent to EFF2)
IE2 - High efficiency (efficiency levels roughly equivalent to EFF1, identical to EPAct in USA)
IE3 - Premium efficiency (identical to "NEMA
Premium" in the USA)
IEC 60034-30 covers almost all motors, with the notable exceptions of motors made solely for converter
operation and motors completely integrated into a machine (and which cannot be tested separately) .
IEC 60034 Efficiency Limits
Efficiency limit values IEC 60034-30; 2008
Output
kw
IE1 - Standard Efficiency IE2 - High Efficiency IE3 - Premium Efficiency
2 pole 4 pole 6 pole 2 pole 4 pole 6 pole 2 pole 4 pole 6 pole
0.75 72.1 72.1 70.0 77.4 79.6 75.9 80.7 82.5 78.9
1.1 75.0 75.0 72.9 79.6 81.4 78.1 82.7 84.1 81.0
1.5 77.2 77.2 75.2 81.3 82.8 79.8 84.2 85.3 82.5
2.2 79.7 79.7 77.7 83.2 84.3 81.8 85.9 86.7 84.3
3 81.5 81.5 79.7 84.6 85.5 83.3 87.1 87.7 85.6
4 83.1 83.1 81.4 85.8 86.6 84.6 88.1 88.6 86.8
5.5 84.7 84.7 83.1 87.0 87.7 86.0 89.2 89.6 88.0
7.5 86.0 86.0 84.7 88.1 88.7 87.2 90.1 90.4 89.1
11 87.6 87.6 86.4 89.4 89.8 88.7 91.2 91.4 90.3
15 88.7 88.7 87.7 90.3 90.6 89.7 91.9 92.1 91.2
18.5 89.3 89.3 88.6 90.9 91.2 90.4 92.4 92.6 91.7
22 89.9 89.9 89.2 91.3 91.6 90.9 92.7 93.0 92.2
30 90.7 90.7 90.2 92.0 92.3 91.7 93.3 93.6 92.9
37 91.2 91.2 90.8 92.5 92.7 92.2 93.7 93.9 93.3
45 91.7 91.7 91.4 92.9 93.1 92.7 94.0 94.2 93.7
55 92.1 92.1 91.9 93.2 93.5 93.1 94.3 94.6 94.1
75 92.7 92.7 92.6 93.8 94.0 93.7 94.7 95.0 94.6
90 93.0 93.0 92.9 94.1 94.2 94.0 95.0 95.2 94.9
110 93.3 93.3 93.3 94.3 94.5 94.3 95.2 95.4 95.1
132 93.5 93.5 93.5 94.6 94.7 94.6 95.4 95.6 95.4
160 93.7 93.8 93.8 94.8 94.9 94.8 95.6 95.8 95.6
200 94.0 94.0 94.0 95.0 95.1 95.0 95.8 96.0 95.8
250 94.0 94.0 94.0 95.0 95.1 95.0 95.8 96.0 95.8
315 94.0 94.0 94.0 95.0 95.1 95.0 95.8 96.0 95.8
355 94.0 94.0 94.0 95.0 95.1 95.0 95.8 96.0 95.8
375 94.0 94.0 94.0 95.0 95.1 95.0 95.8 96.0 95.8
From June 16, 2011 machine builders are only permitted to use high-efficiency motors with
a minimum efficiency class of IE2 (IEC 60034:2008). The new EU Directive 2005/32/EC is
applicable to low-voltage asynchronous motors of 0.75 to 375 kW.
The aim of the change is that by reducing losses, carbon-dioxide emissions and operating
costs are reduced.
Calculation of cost savingsA quick calculation of annual savings is given by:
where:
hrs = annual running time (hours)
kW = motor rating in kW
%FL = fraction of full load power motor is running at
Rate = electricity cost per kWh
ηstd = efficiency of standard motor
ηeff = efficiency of better motor- See more at: http://myelectrical.com/notes/entryid/155/european-motor-efficiency-classification#sthash.gcfQpCQI.dpuf
Power Factor By Steven McFadyen on July 10th, 2012
Power Factor Power factor is the ratio between the real power (P in kW) and apparent power (S in kVA) drawn by an electrical load.
The reactive power (Q in kVAr) causes the real and apparent power to be displaced from each other.
Reactive power provides the necessity for electric and magnetic fields to enable the power system to
work.
In addition to being the ratio of real power to apparent power, the power factor can also be express as the
cosine of the angle between the two.
If the reactive power of the load is inductive, the real power will lag the apparent power and the power
factor will be lagging. If the reactive power is capacitive the power factor will be leading.
In it's simplest form power factor, can also be considered a measure of the useful work obtained from a
power system
Three phase power factor and single phase power factor follow the same concepts
For a theoretical discussion of power factor, see the section on Complex Power on the Alternating
Current Circuits note.
Contents [hide]
1. Typical Power Factors
1. Harmonic Distorted Waveforms
2. Power Factor Correction
1. Power Factor Correction Tool
Typical Power FactorsAverage Power Factor values for the most commonly used plant, equipment and appearances:
plant and appliances cos φ tan φ
induction motor - loaded at 0% 0.17 2.80
induction motor - loaded at 25% 0.55 1.52
induction motor - loaded at 50% 0.73 0.94
induction motor - loaded at 75% 0.80 0.75
induction motor - loaded at 100% 0.85 0.62
lamps incandescent 1.0 0
lamps fluorescent (uncompensated) 0.5 1.73
lamps fluorescent (compensated) 0.93 0.39
lamps discharge 0.4 to 0.6 2.29 to 1.33
oven resistance elements 1.0 0
oven induction heating (compensated) 0.85 0.62
oven dielectric heating 0.85 0.62
resistance type soldering machines 0.8 to 0.9 0.75 to 0.48
arc-welding fixed 1-phase 0.5 1.73
arc-welding motor-generator set 0.7 to 0.9 1.02 to 0.48
arc-welding transformer-rectifier set 0.7 to 0.8 1.02 to 0.75
arc furnace 0.8 0.75
Source: Groupe Schneider - Electrical installation guide
(According to IEC International Standards), 1996
Harmonic Distorted WaveformsExample - true power factor
A load is operating with a displacement power factor of 0.875 and THD of 13.4%. What is
the true power factor?
The distortion power factor is given by:
Resulting in a true power factor of:
Power factor as set up above assumes a sinusoidal wave form. In a modern power system with the
growth of power electronic devices, the waveform is generally not sinusoidal. In this instance the
definition of power factor becomes a little more complicated.
displacement power factor - is the power factor of the 50 Hz fundamental for a
harmonic distorted waveform
distortion power factor - is the amount the displacement power is reduced due to
harmonic content
true power factor - is the actual power factor, taking into account the harmonic
distortion
In a non-sinusoidal waveform the harmonic content reduces the power delivered to the load. True power
factor will always be less than the displacement power factor. The ratio of the true power factor to the
displacement power factor is the distortion power factor. For purely sinusoidal waveforms the distortion
power factor is always 1.
If the total harmonic distortion is know, then the distortion power factor can be found from:
Power Factor CorrectionCalculation of Required kVAr
Existing Situation is defined as load P in kW with power factor pf1 (assume lagging)
Leading to, complex power S1 in kVA
Current Phase angle φ1 is given by:
The desired situation is defined as new power factor pf2
New Phase angle φ2 is give by:
Required compensation Q2 in kVAr:
and
Numerical Example
Existing Situation: P = 450 kW pf1 = 0.83
S1 = 450/0.83 = 542 kVA
φ1 = cos-1(0.83) = 33.9 degrees
Desired Situation: pf2 = 0.95
φ2 = cos-1(0.95) = 18.2 degrees
Calculation Results:
Q2 = 450 * (tan(33.9)-tan(18.2)) = 154 kVAr
S2 = 450/0.95 = 473 kVA (12.7% reduction)
By improving the power factor, power supply authorities need to generate less reactive power and power
distribution systems become more efficient. Power supply authorities often charge a penalty for power
factor and it can be financially beneficial for the owner of equipment to provide systems to improve their
power factor.
Power factor correction is typically carried out by the addition of capacitors – creating reactive power
180o out of phase with that created by the loads (typically inductive).
Power factor correction may be applied as bulk correction at the main plant switchboard or installed
locally at each load.
If the kW is to remain constant then:
and
giving:
Power Factor Correction Tool
Power Factor Correction Unit
The calculation of the amount of reactive power required to achieve a given improvement is relatively
easy to calculate.
To assist in the calculation of required power factor compensation we have added a power factor
correction calculation tool to our site. See the links below for details.
myElectrical's Power Factor Calculator - easy to use online calculator- See more at: http://myelectrical.com/notes/entryid/197/power-factor#sthash.rrRDwsUf.dpuf
By Steven McFadyen on April 2nd, 2012
Anyone specifying or using electric motors should have a basic understanding how the insulation is related to temperature. Three classes of insulation are in common use (with 'F' being the most common):
class B - with a maximum operating temperature of 130 oC
class F - with a maximum operating temperature of 155 oC
class H - with a maximum operating temperature of 180 oC
The image (which is form an ABB catalogue for their low voltage performance motors), shows how
temperature rise is distributed across the insulation.
Typically motors are designed for a maximum ambient temperature of 40 oC.
The difference between the average winding temperature and any hot spot is limited and it is usual to
allow a 10 oC margin for class 'B' and 'F' insulation and a 15 oC margin for class 'H'.
Considering the ambient temperature and hot spot allowance gives the maximum temperature rise within
which the motor must be designed to operate (105 oC for class 'F' for example).
When specifying (buying) a motor there are a couple of options. An insulation class could be specified
and the motor specified as designed to run within that class. Alternatively the motor could be specified for
an insulation class, but be design to run at a low class (for example insulation class 'F', temperature rise
'B').
The advantage of the second method is that there is an inherent 25 oC safety margin - useful if you are in
a region with high ambient temperatures or need to date the motor for some other reason. Running
motors at a reduced temperature will also significantly extend the useful life.- See more at: http://myelectrical.com/notes/entryid/122/understanding-electric-motor-insulation-temperature#sthash.Isv7Ieas.dpuf
By Steven McFadyen on March 28th, 2012
Danfoss Variable Frequency Drives
Variable frequency drives are widely used to control the speed of a.c. motors. This note
looks at the mechanisms which enable drive units to control the speed. In addition to speed,
other advantages offered by variable speed drives are investigated.
Contents [hide]
1. Speed Control of AC Motors
1. General Theory
2. Frequency Control of Speed
3. Circuit Operation
4. Motor Cooling & Derating
2. Variable Speed Drive Units
1. Feature & Considerations
2. Multiple motors on one unit
3. Galvanic Isolation
4. Power Flow and Quadrants
5. See Also
Speed Control of AC MotorsGeneral TheoryThe speed of an a.c. motor is given by:
Where:
f = frequency, Hz
p = number of pole pairs
S = slip
It is possible to vary the speed of a motor by changing any of the above variables (frequency, pole pairs
or slip). However, many of these techniques have some problems associated with them and the most
popular method is that of varying frequency.
Frequency Control of Speed
Pulse Width Modulation
In frequency control, the variable frequency drive (inverter) supplies a series of dc voltage pulses to the
motor terminals at a high frequency (typically 1000 to 10000 Hz). The width of the pulses is varied so that
the average voltage seen by the motor is a sine wave (of a given frequency). Changing the width and
frequency of the dc pulses varies the frequency of the voltage applied to the motor (and hence the motor
speed). This method of frequency control is called pulse width modulation (PWM).
The frequency controller can never give a perfect sinusoidal voltage and hence harmonics will be present.
In addition, the motor will generate more noise and high losses.
As the frequency is changed the applied voltage to the motor, is also changed (such that the ratio of
voltage to frequency is held constant). This is necessary to provide a constant torque over the operating
range.
Circuit OperationThe circuit shows the basic power operation of a variable frequency drive.
Simple Frequency Drive Power Circuit
Diodes (or silicon controlled rectifiers, SCR) on the left side form a three phase rectifier whose job is to
convert the incoming a.c. supply to a d.c. The arrangement shown is that of a six pulse rectifier. More
advance twelve and eighteen pulse rectifiers using phase shifting transformers, which while more
expensive can provide a smooth d.c. and generate less harmonics.
The d.c. capacitor acts as an energy store to provide a more constant d.c. voltage to the inverter.
Insulated-gate bipolar transistor (IGBT) on the right side for the inverter and generate the PWM signal.
The IGBT act as switches which are turned on by applying a signal to the transistor get connection. By
turning on the top IGBT, positive d.c. pulses are generated, whereas the bottom transistors generate
negative pulses. Control circuits with the drive control the width of each pulse to generate the PWM
signal.
Motor Cooling & DeratingAs the PWM waveform is not truly sinusoidal, increase losses will be developed within the motor and will
be shown by an increase in the running temperature of the motor. In addition, when the speed of the
motor is reduced, the cooling effect will also be reduced and additional external cooling may be required.
The characteristics of the motor need to be considering in deciding if there is a need for additional
external cooling.
Due to the increase in losses associated with using a variable speed drive and in the absence of specific
motor data, as a rule of thumb it is recommended that motor output be derated by 10%.
Note: he higher the switching frequency the closer the output will match that of a sine
wave. However, due to increased switching the IGBT will incur more losses.
Variable Speed Drive UnitsFeature & ConsiderationsIn addition to basic speed control, modern variable speed drive units have many additional features and
benefits. Some of these features are listed below.
Acceleration & Deceleration
Drive units allow adjustable acceleration and deceleration rates allowing the speed of
motors to be gradually increased or decreased.
Drive units can also monitor the acceleration (by current) and deceleration (by dc bus
voltage) and hold the acceleration /deceleration ramp if the motor is about to stall.
This can prevent nuisance tripping during the starting of high inertia loads.
Motor Protection
Drive units provide full electrical protection for the motor, including over current, over
voltage, under voltage, over temperature, and earth leakage.
Boost
Normally the output voltage is changed so that the voltage / frequency ratio is kept
constant, thereby giving a constant torque. In some situations, it is beneficial to alter
this pattern and most modern drive units allow several different patterns to be
selected. By altering the voltage frequency ratio, different torque characteristics can
be obtained (i.e. higher or lower starting torque, etc.).
Braking
Breaking of a motor can be achieved by allowing it to naturally coast to a stop,
injecting a dc current or by regenerative breaking (supplying power back into the
mains grid or dissipating it across a resistor). Modern drive units can allow all these
types of breaking.
Injecting a dc current into the stator of a motor causes the rotating magnetic field to
collapse and the rotor to stall. Normally drive units allow both the length of breaking
and magnitude of breaking to be controlled by varying the dc current injected. Care
should be taken to ensure that both the time and length of braking are set correctly
for the connected load.
Regenerative breaking takes the inertia of the load and converts this in the electrical
energy, which is fed back into the mains grid (or dissipated across a resistor).
Reversing Operation
Variable speed drive units allow the motor to be operated in reverse (without any
changing of the phase of the motor supply cables).
Maximum & Minimum Frequency
Variable speed units allow the maximum and minimum frequency of use to be set. The
means that regardless of setting of the speed control input, the load can always be run
under safe conditions.
Skip Frequencies
Sometimes resonance occurs within a motor at certain frequencies. Drive units allow
bands of skip frequencies to be programmed which will allow the controller to pass
quickly through these bands during acceleration and deceleration.
Speed Control Input
The speed control input to a variable speed drive unit can take many forms. Most
typically this would be a potentiometer on the front of the unit or an external analogue
signal (4-20 mA or 0-10V).
Multiple motors on one unitIt is possible to connect multiple motors to one variable frequency drive. This has the advantages of cost
saving and a simpler installation. On the other hand all motors will need to be run in an identical
operating mode.
If this technique is used, it should be noted that with several motors the variable frequency drive will be
unable to detect any overload in an individual motor. Each motor will need it's own overload device.
Galvanic IsolationGalvanic isolation is applied to the control terminals of the variable speed drive and provides a barrier
between these terminals and the rest of the drive. If any of the control inputs or outputs is accidentally
earthed, the galvanic isolation should protect the sensitive electronics.
Power Flow and Quadrants
VFD Quadrants Power flow within a variable frequency drive can be defined by four quadrants (see image):
Quadrant 1 - the motor is rotating clockwise, with the torque the same direction
(motor accelerating)
Quadrant 2 - the motor is rotating clockwise, but the torque in the reverse direction
(motor accelerating)
Quadrant 3 - motor and torque are rotating in the opposite direction (motor
accelerating)
Quadrant 4 - motor rotating in the
Understanding Motor Duty Rating By Steven McFadyen on December 12th, 2011
One of the comments on my Motor Starting Series was asking for something on duty cycles. Here it
is.
As a purchaser of a motor, you have responsibility to let the manufacturer know the anticipated duty of the
motor. To assist in the communication of this information, the standard IEC 60034-1 (Rotating electrical
machines) defines several duty characteristics, denoted S1 to S10:
S1 Continuous duty The motor operates at a continuous load for sufficient
time to enable machine to reach thermal equilibrium.
S2 Short Time duty Operation at a load for a time not sufficient to reach
thermal equilibrium, followed by enough time for the
motor to cool down.
S3 Intermittent periodic
duty
Series of identical duty cycles each a constant load for a
period, followed by a rest period. Thermal equilibrium is
not reached during the cycle.
S4 Intermittent periodic
duty with starting
Similar to S3, but there is a significant starting time within
the periodic operation.
S5 Intermittent periodic
duty with electric
braking
Sequence of identical duty cycles - starting, operation,
braking and rest. Again thermal equilibrium is not
reached.
S6 Continuous operation
periodic duty
Identical duty cycles with a period at load followed by a
period at no load. Difference between S1 is that the
motor runs at no-load, without actual stopping.
S7 Continuous operation
periodic duty with
electric braking
As per S6, but with a significant starting and electric
breaking periods. Again motor operates at no-load for
period instead of stopped.
S8 Continuous operation
periodic duty with
related load/speed
changes
Series of identical repeating duty cycles, where within
each cycle the motor operates at several different load
levels and speed. There is not stopped time and thermal
equilibrium is not reached.
S9 Duty with non-periodic
load and speed
variations
Load and speed vary periodically within the permissible
operating range. Frequent overloading may occur.
S1
0
Duty with discrete
constant loads and
speeds
Duty with discrete number of load/speed combinations,
with these maintained long enough to reach thermal
equilibrium.
Thermal Equilibrium is the state reached when the temperature rise of the machine does not vary by more
than 2K per hour. If you don't specify the duty cycle, the manufacturer will likely assume S1. Click on the
image to see a larger version, illustrating the duty cycles.
If anyone has anything to add, please do so below.
Estimating Power Demand Using IEC Methods By Steven McFadyen on July 27th, 2011
Estimating power demand is combination of science and art. It is an area of electrical engineering where there is no correct answer. Plug the figures in your preferred method of calculation and then as an engineer you need to relay on instincts to say if the answer feels right or not. This is a look at one method inline with what could be considered IEC practice.
reproduced from Schneider's 'Electrical Installation Guide - According to IEC International Standards' Estimating power demand is combination of science and art. It is an area of electrical engineering where there is no correct answer. Plug the figures in your preferred method of calculation and then as an engineer you need to relay on instincts to say if the answer feels right or not.
Individual loads do not necessarily operate at full rated nominal power nor at the same time. Estimating
power demand involves both looking at the total connected load and the maximum expected demand on
the system. As we will see these are not the same.
Contents [hide]
1. IEC Method
2. Typical Utilisation & Simultaneity Factors
1. Utilization Factor (ku)
2. Simultaneity Factor (ks)
3. Basic Demand Data and Preliminary Planning
4. Related Links
IEC MethodDepending where you are, different methods, figures and procedures are used to estimate the power
demand of an installation. This is a look at one method inline with what could be considered IEC practice.
To get going it is useful to understand some basic definitions:
voltage V - the voltage of the electrical system
load current Ib - the current required to operate an item of equipment
apparent power kVA - the product of the voltage V and load current Ib
real power kW - the actual power consumed by the load or equipment
power factor - the ratio of the real power to apparent power (kW/kVA)
utilisation factor ku - see below
simultaneity factor ks - see below
Utilisation factor ku - name plate ratings invariably list higher values of current than will
be seen in use, motors rarely run at full load, etc. A utilisation factor can be applied to these
ratings to establish a more realistic load current, thereby not overestimating the demand.
Simultaneity factor ks - not all equipment runs a the same time; for example one motor
may be duty and the other standby. The same applies to installations; for example a group
of houses or apartments will not all consume the full design current at the same time.
Applying a simultaneity factor takes care of this. Often the term diversity is used and has
the same meaning.
The diagram illustrates how the utilisation and simultaneity factors are used to estimate the power
demand of an installation. Click on the image for a larger version.
Following the diagram, the apparent power of the load or equipment is multiplied by the utilisation factor
to give a realistic power demand to be supplied by a distribution board. Summing these power demand
figures gives the total connected apparent demand (at that board). The distribution board would normally
be sized for this demand.
An appropriate simultaneity factor is applied to the connected apparent demand at the distribution board
and this [diversified] load is carried upstream to higher levels boards. Repeating this procedure will lead to
an expected total demand for the full installation.
In a nutshell, that’s all there is to it - in principal at least. There are often problems in deciding what
simultaneity factor to use and here experience can be really useful.
Tip: estimating power demand this is normally carried out using either apparent or real
power. I prefer real power as it gives me the actual kW required and is an algebraic sum.
Many people will use apparent power, which strictly speaking is a vector sum. As we are
dealing with estimates (ball park figures even), using either real or apparent power will yield
usable results.
Typical Utilisation & Simultaneity FactorsIdeally utilisation and simultaneity factors should be developed specifically for each application and based
on a knowledge of how that particular system will operate. For certain situations it may be necessary to
use factors given by supply authorities or some other industry adopted factors.
The factors below are based on those given in the Schneider Electrical Installation Guide and can be
used in the absence of other sources or to provide reality checks on figures being used.
Utilization Factor (ku)Actual power used in equipment is often less than the rated power. A utilization factor (ku) is used to give
a more realistic estimation of maximum power.
Typical values of Utilization Factor ku:
Type of load ku
Motors (Typical 0.75
Lighting
Circuits
1
Socket Outlets 0.1 to 0.2
Simultaneity Factor (ks)If is rare in practice that all loads operate simultaneously. The simultaneity factor ks is
applied to each group of loads (e.g. being supplied from a distribution or sub-distribution
board). Simultaneity factor is sometimes called diversity factor.
Typical values of Simultaneity Factor ks by circuit function:
Type of load ks
Lighting 1
General Heating 1
Space Heating 0.8
Air Conditioning 1
Socket Outlets 0.1 to 0.2
Building Installations ks
Escalator 0.5
Elevator 0.3
Sanitary systems 0.5
Sprinklers 0.1
Heating 0.8
Apartment Blocks
ks
2 to 4 1
5 to 9 0.78
10 to 14 0.63
15 to 19 0.53
20 to 24 0.49
Type of load ks
Lifts/Hoists Most powerful motor
1
Second most powerful motor
0.75
For all motors 0.6
Assemblies -Number of Circuits ks
2 and 3 0.9
4 and 5 0.8
6 to 9 0.7
10 and more 0.6
Air conditioning 0.8
Cooling water system 0.7
Refrigeration 0.7
25 to 29 0.46
30 to 34 0.44
35 to 39 0.42
40 to 49 0.41
50 and more 0.40
We've produced an Excel spreadsheet for estimating building total connected load and
maximum demand.
If your interested in obtaining a copy, you can get it here.
Basic Demand Data and Preliminary PlanningSiemens produce a series of publications providing typical demand figures for various building functions
[see Steven's Technical List, Buildings Technology for a list of these]. The following tables are based
on values given in these publications:
Buildings according to their type of use:
Building Use Average Power Demand
Simultaneity Factor
Different functional and building areas
Functional Area/ Building Area
Average Power Demand
Simultaneity Factor
Bank 40-70 w/m2 0.6
Library 20-40 w/m2 0.6
Office 30-50 w/m2 0.6
Shopping centre 30-60 w/m2 0.6
Hotel 30-60 w/m2 0.6
Department store 30-60 w/m2 0.6
Small hospital (40-80 beds)
250-400 w/m2
0.6
Hospital (200-500 beds)
50-80 w/m2 0.6
Warehouse (no cooling) 2-20 w/m2 0.6
Cold store 500- 1,500 w/m2
0.6
Apartment complex (without night storage or continuous-flow water heater)
10-30 w/m2 0.6
Museum 60-80 w/m2 0.6
Parking garage 3-10 w/m2 0.6
Production plant 30-80 w/m2 0.6
Data centre 500-2,000 w/m2
1 .0
School 10-30 w/m2 0.6
Gym hall 15-30 w/m2 0.6
Stadium (40,000-80,000 seats)
70-120 w/seat
0.6
Old people’s home 15-30 w/m2 0.6
Greenhouse (artificial 250-500
Hallway, anteroom or lobby
5-15 w/m2 0.3
Staircase 5-15 w/m2 0.3
General utilities 5-15 w/m2 0.3
Foyer 10-30 w/m2 1.0
Access ways (e.g. tunnel)
10-20 w/m2 1 .0
Recreation room/kitchenette
20-50 w/m2 0.3
Toilet areas 5-15 w/m2 1 .0
Travel centre 60-80 w/m2 0.8
Office areas 20-40 w/m2 0.8
Bookstore 80-120 w/m2 0.8
Flower shop 80-120 w/m2 0.8
Bakery/butcher 250-350 w/m2
0.8
Groceries 80-120 w/m2 0.8
Bistro/ice cream parlour 150-250 w/m2
0.8
Cafe 180-220 w/m2
0.8
Diner/restaurant 180-400 w/m2
0.8
Tobacco shop 80-120 w/m2 0.8
Hairdresser 220-280 w/m2
0.8
Dry-cleaner’s or laundry 700-950 w/m2
0.7
Storage area 5-15 w1/m2 0.3
lighting) w/m2
Office Equipment Demand
Recommendations
Equipment Average Power Demand
Data Source
All in one Printer/ Fax/Scanner
75 w CIBSE
Ceiling Projector Lift 50 w Estimated
Ceiling Projector Screen
80 w Estimated
Colour Printer/Copier 200 w CIBSE
Colour Scanner 50 w CIBSE
Computer Peripherals 400 w Estimated
Convenience Sockets 200 w/socket DEWA
Cost Recovery Devices 3,000 w Estimated
Desktop 100 w CIBSE
DVD Player 70 w Estimated
Fixed Camera 30 w Estimated
Laptop 100 w CIBSE
Large Smart Board 300 w Estimated
Monitor 200 to 400 W CIBSE
Paper Shredder 50 w CIBSE
Personal Printer/Fax 50 w CIBSE
Portable Wireless Controller 20 w Estimated
Projector 300 w CIBSE
Other areas:
Area Average power demand
Electric floor heating bedrooms
65-1 00 w/m2
Electric floor heating bathroom
130-150 w/m2
Night storage heating: Low-energy house
60-70 w/m2
Night storage heating: house with “standard” insulation
100-110 w/m2
Small air conditioning unit 60 w/m2
Photovoltaic (maximum output of the modules)
100-130 w/m2
Rack Equipment in Credenza
400 W Estimated
Shredder 190 w Estimated
Technology Wells in Table Top
200 w Estimated
Teleconference Module 50 w Estimated
Wall Mounted Controller 20 w Estimated
Wall Mounted LCD 200 w Estimated
Related Links - See more at: http://myelectrical.com/notes/entryid/74/estimating-power-demand-using-iec-
methods#sthash.UGG8ltey.dpuf
v- See more at: http://myelectrical.com/notes/entryid/106/understanding-motor-duty-
rating#sthash.9oAZkHer.dpuf opposite direction, with clockwise torque (motor
decelerating)
Differing types of equipment will operate in different quadrants, for example pumps typically operate only
in quadrant 1, while an electrical car would use all four quadrants.
- See more at: http://myelectrical.com/notes/entryid/152/variable-frequency-drive#sthash.YpZKLRbL.dpuf
By Steven McFadyen on March 1st, 2010
ABB has produced a range of technical guides that offer concise explanations of the major technologies and technical issues in low voltage AC drives. The technical guides cover subjects such as the basics of variable-speed drives, dimensioning a drive system, electrical braking, harmonics and AC drives, and bearing currents.
Currently the ABB site lists the following guides:
Application Guide, Guide to extruders in AC drives
Sustainability guide, Driving energy efficiency worldwide, ABB motors and drives
Technical Guide, Direct Torque Control
Technical guide, Functional safety
Application guide, ABB drives, Using variable speed drives (VSDs) in pump applications
Technical Guide, EU Council Directives and Adjustable Speed Electrical Power Drive
Systems
Technical guide, EMC compliant installation and configuration for a power drive system
Technical Guide, Guide to Variable Speed Drive
Technical Guide, Bearing Currents in Modern AC Drive Systems
Technical Guide, Guide to Harmonics with AC Drives
Technical Guide, Dimensioning of a Drive system
Technical Guide, Electrical Braking
Technical guide, Guide to motion control drives
The guides can be accessed at:
ABB Technical Guides - Motor Operation- See more at: http://myelectrical.com/notes/entryid/34/abb-technical-guides-motor-operation#sthash.VU2L2KBU.dpuf