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Equipment Damage Curves Transformers

  
     
  The information presented in this application guide is for review, approval, interpretation and application by a registered professional engineer only. SKM disclaims any responsibility and liability resulting from the use and interpretation of this information.

Reproduction of this material is permitted provided proper acknowledgement is given to SKM Systems Analysis Inc.

Purpose

The purpose of this guide is to provide basic information about transformer through-fault damage curves and characteristic landmarks necessary for plotting on time-current curves, for the purpose of equipment overcurrent protection. Damage curves are defined in the IEEE standards in per unit on the nominal base rating (kVA) of the transformer, and are not adjusted with changes to the core, winding material or method of cooling.

Full Load Amps (FLA)

FLA is the rated continuous current carrying capacity of a transformer at a referenced ambient temperature and allowable temperature rise, see table 1. The FLA label is located on a time-current curve (TCC) in top decade at 1000 seconds.
The total temperature rise of an OA 65°C transformer, at an average/maximum ambient temperature of 30/40°C, is 110/120°C. These temperatures do exceed the transformer insulation rating of 105°C, and are allowed by the standards. 		 
  Table 1 Transformer temperature ratings  
 
Cooling
Method		 Ave/Max
Amb. Temp.		 Hot Spot
Temp.		 Temp.
Rise		 Total Temp.
Rise		 Insul.
Temp.		 Max Winding
SC Temp.
AA 30°C/40°C

15°C
20°C
25°C
30°C
30°C

 75°C
90°C
115°C
130°C
150°C		 120°C/130°C
140°C/150°C
170°C/180°C
190°C/200°C
210°C/220°C		 130°C
150°C
180°C
200°C
220°C		 300°C
350°C
400°C
425°C
450°C
ONAN (OA) 30°C/40°C 10°C
15°C		 55°C
65°C		 95°C/105°C
110°C/120°C

105°C

 200°C-Al
250°C-CU
 
  SC Withstand Capability (Damage) Curves

ANSI C57.109 defines damage characteristics for oil-filled, power transformers see tables 2-5. ANSI C57.12.59 defines damage characteristics for dry-type transformers see table 6 and 7. The through-fault current damage curves are not intended for overload capability. The standards state, “if fault current penetrates the limits of the thermal damage curve insulation may be damaged, or if fault current penetrates the limits of the mechanical damage curve cumulative mechanical damage may occur. The validity of these damage limit curves can not be demonstrated by test, since the effects are progressive over the transformer lifetime. They are based principally on informed engineering judgment and favorable, historical field experience.” 		 
  The damage curves are plotted in the top 3 decades of a TCC from 2 to 1000 seconds.  
 
Table 2 Category I Liquid-Immersed Transformers
5-500kVA 1-Ø
15-500kVA 3-Ø
Frequent (Mechanical Damage)
or Infrequent Faults (Thermal Damage)
x Rated Current Time I2t 1-Ø 3-Ø
(A p.u.) (sec.) (A p.u.-sec.) (kVA) (kVA)
2 1800 7200 5-500 15-500
3 300 2700 5-500 15-500
4.75 60 1354 5-500 15-500
6.3 30 1191 5-500 15-500
11.3 10 1277 5-500 15-500
25 2 1250 5-500 15-500
35 1.02 1250 5-100 15-300
40 0.78 1250 5-75 15-75
 
 

Table 3 Category II Liquid-Immersed Transformers

501-1667kVA 1-Ø

501-5000kVA 3-Ø

Infrequent Faults (Thermal Damage)

x Rated Current

Time

I2t

(A p.u.)

(sec.)

(A p.u.-sec.)

2

1800

7200

3

300

2700

4.75

60

1354

6.3

30

1191

11.3

10

1277

25

2

1250

Frequent Faults (Include Infrequent Points Plus)

Mechanical Damage Points

x Rated Current

Time

I2t

(A p.u.)

(sec.)

(A p.u.-sec.)

0.7 / Z

2551 Z2

1250

0.7 / Z

4.08

K

1.0 / Z

2

K
 
 

Table 4 Category III Liquid-Immersed Transformers

1668-10,000kVA 1-Ø

5001-30,000kVA 3-Ø

Infrequent Faults (Thermal Damage)

x Rated Current

Time

I2t

(A p.u.)

(sec.)

(A p.u.-sec.)

2

1800

7200

3

300

2700

4.75

60

1354

6.3

30

1191

11.3

10

1277

25

2

1250

Frequent Faults (Include Infrequent Points Plus)

Mechanical Damage Points

x Rated Current

Time

I2t

(A p.u.)

(sec.)

(A p.u.-sec.)

0.5 / Z

5000 Z2

1250

0.5 / Z

8

K

1.0 / Z

2

K
 
 
Table 5 Category IV Liquid-Immersed Transformers

1668-10,000kVA 1-Ø

5001-30,000kVA 3-Ø

Frequent (Mechanical Damage)
or Infrequent Faults (Thermal Damage)

x Rated Current

Time

I2t

(A p.u.)

(sec.)

(A p.u.-sec.)

2

1800

7200

3

300

2700

4.75

60

1354

6.3

30

1191

11.3

10

1277

25

2

1250

Frequent (Mechanical Damage)
or Infrequent Faults (Thermal Damage)

x Rated Current

Time

I2t

(A p.u.)

(sec.)

(A p.u.-sec.)

0.5 / Z

5000 Z2

1250

0.5 / Z

8

K

1.0 / Z

2

K
 
  IEEE Std C57.12.01 defines 3 categories of dry-type transformers. However, IEEE Std C57.12.59 only defines damage curves for Category I and II transformers.  Damage curves for Category III transformers, 1668-10,000kVA 1-Ø, 5001-30,000kVA 3-Ø are not defined.  
     
 

Table 6 Category I Dry-Type Transformers

1-500kVA 1-Ø

15-500kVA 3-Ø

Frequent (Mechanical Damage)
or Infrequent Faults (Thermal Damage)

x Rated Current

Time

I2t

(A p.u.)

(sec.)

(A p.u.-sec.)

3.5

100

1250

11.2

10

1250

25

2

1250
 
 
Table 7 Category II Dry -Type Transformers

501-1667kVA 1-Ø

501-5000kVA 3-Ø

Infrequent Faults (Thermal Damage)

x Rated Current

Time

I2t

(A p.u.)

(sec.)

(A p.u.-sec.)

3.5

100

1250

11.2

10

1250

25

2

1250

Frequent Faults (Include Infrequent Points Plus)

Mechanical Damage Points

x Rated Current

Time

I2t

(A p.u.)

(sec.)

(A p.u.-sec.)

0.7 / Z

2551 Z2

1250

0.7 / Z

4.08

625

1.0 / Z

2

625
 
     
 

Magnetizing Inrush Current Point(s)


One or more inrush current points may be plotted on a TCC.  Inrush currents are expressed in peak amps.  The most common point is 8-12 times rated FLA at 0.1 seconds.  Another less common point is 25 times rated FLA at 0.01 seconds. 


Example 1


Plot the characteristic landmarks for a 1000kVA, 65°C, 4160-480/277V, Δ-YG, oil-filled, substation transformer with an impedance of 6.0%.  Consider both the frequent and infrequent fault cases for this application. 


Solution


Step 1 – Calculate the FLA

FLA = 1000kVA / (1.732 x 4.16kV) = 139 amps 

Step 2 – Determine the Applicable Category

This is a Category II transformer based on the nominal rating of 1000kVA

Step 3 – Calculate the infrequent fault data points from Table 3

I 1800 sec = 2 x 139 amps = 278 amps
I 300 sec = 3 x 139 amps = 417 amps
I 60 sec = 4.75 x 139 amps = 660 amps
I 30 sec = 6.3 x 139 amps = 876 amps
I 10 sec = 11.3 x 139 amps = 1571 amps
I 2 sec = 25 x 139 amps = 3475 amps

Since the transformer is connected Δ-YG a separate set of data points must be calculated for primary-side protective devices.  Primary-side devices will only see 58% of a secondary-side, single-line-to-ground fault.

I 1800 sec = 0.58 x 2 x 139 amps = 161 amps
I 300 sec = 0.58 x 3 x 139 amps = 242 amps
I 60 sec = 0.58 x 4.75 x 139 amps = 383 amps
I 30 sec = 0.58 x 6.3 x 139 amps = 508 amps
I 10 sec = 0.58 x 11.3 x 139 amps = 911 amps
I 2 sec = 0.58 x 25 x 139 amps = 2016 amps

Step 4 – Calculate the frequent fault data points from Table 3

I 2 sec = 139 amps / Z = 139 amps / 0.06 = 2316 amps
I 4.08 sec = 0.7 x 139 amps / Z = 97.3 amps / 0.06 = 1622 amps
t 1622 amps = 2551 (0.06)2 = 9.2 seconds

Again, shift the data points by 0.58.

I 2 sec = 0.58 x 139 amps / 0.06 = 1344 amps
I 4.08 sec = 0.58 x 97.3 amps / 0.06 = 941 amps

Step 5 – Calculate Inrush Points

12 x Inrush = 12 x 139 amps = 1668 amps
25 x Inrush = 25 x 139 amps = 3475 amps

The results are plotted in figure 1.


Example 2


Repeat Example 1 but now assume the secondary is high-resistance grounded (HRG). 


Solution


Step 1 – Same as Example 1
Step 2 – Same as Example 1
Step 3 – Same as Example 1

No shifting of the damage curve is required with a HRG secondary.  In this case the primary-side protective devices will not see a ground fault on the secondary-side.  Ground fault magnitudes will always be much lower than load current levels. 

Step 4 – Same as Example 1

Again, no shifting of data points is required.

Step 5 – Same as Example 1

The results are plotted in figure 2.

  
     
   
  Fig. 1 1000kVA, Δ-YG, liquid-immersed transformer damage curves  
   
  Fig. 2 1000kVA, Δ-YG (HRG), liquid-immersed transformer damage curves  
     
 

Example 3


Plot the characteristic landmarks for a 1500kVA, 150°C, 13800-480/277V, Δ-Δ, dry-type, substation transformer with an impedance of 5.75%.  Consider the infrequent fault case for this application.


Solution


Step 1 – Calculate the FLA

FLA = 1500kVA / (1.732 x 13.8kV) = 62.8 amps 

Step 2 – Determine the Applicable Category

This is a dry-type, Category II transformer based on the nominal rating of 1500kVA

Step 3 – Calculate the infrequent fault data points from Table 7

I 100 sec = 3.5 x 62.8 amps = 220 amps
I 10 sec = 11.2 x 62.8 amps = 703 amps
I 2 sec = 25 x 62.8 amps = 1570 amps

Since the transformer is connected Δ-Δ a separate set of data points must be calculated for primary-side protective devices.  Primary-side devices will only see 87% of a secondary-side, line-to-line fault.

I 100 sec = 0.87 x 3.5 x 62.8 amps = 191 amps
I 10 sec = 0.87 x 11.2 x 62.8 amps = 612 amps
I 2 sec = 0.87 x 25 x 62.8 amps = 1366 amps

Step 4 – Calculate Inrush Points

12 x Inrush = 12 x 62.8 amps = 754 amps
25 x Inrush = 25 x 62.8 amps = 1570 amps

The results are plotted in figure 3.

  
   
  Fig. 3 1500kVA, Δ- Δ, dry-type transformer damage curves  
     
  References  
     
  •   Other Application Guides offered by SKM Systems Analysis at www.skm.com
•   ABB Protective Relaying Theory and Application, 2nd Edition, 2004 		 
  The latest revision of:  
  •   IEEE Std 242, IEEE Recommended Practice for Protection and Coordination of Industrial and Commercial Power Systems (IEEE Buff Book)
•   EEE Std C57.12.00, IEEE Standard General Requirements for Liquid-Immersed Distribution, Power and Regulating Transformers
•   IEEE Std C57.12.01, IEEE Standard General Requirements for Dry-Type Distribution and Power Transformers Including Those with Solid-Cast and/or Resin-Encapsulated Windings
•   IEEE Std C57.12.59, IEEE Guide for Dry-Type Transformer Through-Fault-Current Duration
•   IEEE Std C57.109, IEEE Guide for Liquid-Immersed Transformer Through-Fault-Current Duratio		  
     
  Insulating materials  
     
 
Insulation
Class

Maximum
Temperature

Insulating Materials

Y

90°C

Cotton, silk, paper, wood,
cellulose, fibre without
impregnation or oil-immersion

A

105°C

Class Y impregnated with natural resins,
cellulose esters, insulating oils, etc.,
also laminated wood, varnished paper

Hybrid A

110°C

TInsuldur® InsulationT
Kraft paper with epoxy binders
activated under pressure

E

120°C

Synthetic-resin enamels, cotton
and paper Laminates 
with formaldehyde bonding

B

130°C

Mica, glass fibre, asbestos, etc., with
suitable bonding substance; built-up mica,
glass-fibre and asbestos laminates

F

155°C

The materials of Class B with more
thermally-resistant bonding materials

H

180°C

Glass-fibre and asbestos materials,
and built-up mica, with appropriate
Silicone resins

C

>180°C

Mica, ceramics, glass, quartz, and
asbestos without binders or with silicone
resins of superior thermal stability

> H

220°C

TNOMEX® insulation,
varnish dipped and vacuum pressure
impregnated (VPI)
 
     
     
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