p r 11 hydro p.o. box 12400. st. john's. ni hydro place ... · documentation would be supplied...

Ai\p r I newfoundland labrador

11 hydro a nalcor energy company

Hydro Place. 500 Columbus Drive.

P.O. Box 12400. St. John's. NI

Canada A1B 4K7

t. 709.737.1400 f. 709.737.1800

www.n1h.nl.ca

December 17, 2014

The Board of Commissioners of Public Utilities

Prince Charles Building

120 Torbay Road, P.O. Box 21040

St. John's, Newfoundland & Labrador

A1A 5B2

Attention: Ms. Cheryl Blundon

Director Corporate Services & Board Secretary

Dear Ms. Blundon:

Re: Newfoundland and Labrador Hydro - the Board's Investigation and Hearing into Supply Issues and Power Outages on the Island Interconnected System: Supplementary Response in Relation to PUB-NLH-457 and PUB-NLH-458

In its responses to the Board's RFIs PUB-NLH-457 and PUB-NLH-458, Hydro indicated that additional

documentation would be supplied to the Board when the related work was completed. In this regard,

please find enclosed the original and 12 copies of the following:

a) Hydro's analysis of the impact of transmission line contingencies on system losses related to

alternate generation dispatches (re: PUB-NLH-457); and,

b) Two reports by Trans Grid Solutions Inc. related to the simulation of the Sunnyside Ti failure and

an investigation of the Western Avalon T5 transformer failure concerning whether or not

harmonics or system resonance were contributing factors to the system events of January, 2014

(re: PUB-NLH-458).

We trust the foregoing is satisfactory. If you have any questions or comments, please contact the

undersigned.

Yours truly,

NEWFOUNDLAND AND LABRADOR HYDRO

Tracey UPennell

Legal Counsel

TLP/jc

cc: Gerard Hayes — Newfoundland Power

Thomas Johnson — Consumer Advocate Paul Coxworthy — Stewart McKelvey Stirling Scales

Danny Dumaresque

ecc: Roberta Frampton Benefiel — Grand Riverkeeper Labrador

Engineering Support Services for:

Sunnyside Transformer T1 Fire

Newfoundland and Labrador Hydro

Attention:

Mr. Peter Thomas

Report R1335.01.00

PSCAD Investigation of the Sunnyside T1 Transformer Failure

Prepared by:

TransGrid Solutions Inc. 200 – 150 Innovation Dr.

Winnipeg, MB R3T 2E1

CANADA

www.transgridsolutions.com

Oct 5th, 2014

Reference: PUB-NLH-458 Atth 2

Newfoundland and Labrador Hydro Sunnyside Transformer T1 Fire


Disclaimer

This report was prepared by TransGrid Solutions Inc. (“TGS”), whose responsibility is limited to the scope of work

as shown herein. TGS disclaims responsibility for the work of others incorporated or referenced herein. This report

has been prepared exclusively for Newfoundland and Labrador Hydro and the project identified herein and must

not be reused or modified without the prior written authorization of TGS.

Revisions

Project Name: Sunnyside Transformer T1 Fire

Document

Title:


Document

Type:

Draft report

Document No.: R1335.01.00

Last Action

Date:

Oct 5th, 2014

Rev.

No.

Status Prepared By Checked By Date Comments

00 IFC D. Kell R. Kolt 05/10/14

01

Legend of Document Status:

Approved by Client ABC

Draft for Comments DFC

Issued for Comments IFC

Issued for Approval IFA

Issued for Information IFI

Returned for Correction RFC

Approval not Required ANR




R1335.01.00 2 Oct 5th, 2014

© TransGrid Solutions Inc, 2014

Table of Contents

1. Introduction .............................................................................................................................................. 3 2. PSCAD Model Development ....................................................................................................................... 5

2.1 AC System model ......................................................................................................................................... 5

2.2 AC Transmission Lines .................................................................................................................................. 7

2.3 Power Transformers ..................................................................................................................................... 9

2.4 T5 Transformer at Sunny Side and T1 Transformer at Western Avalon .................................................... 10

2.5 PSCAD Model Benchmarking Against PSS/E............................................................................................... 12

3. Modeling of Fault...................................................................................................................................... 14

3.1 Transformer Fault ...................................................................................................................................... 14

4. Results ...................................................................................................................................................... 15 5. Conclusions and Recommendations .......................................................................................................... 19

List of Figures Figure 1‐1 Example of Low resolution waveforms ........................................................................................................ 3

Figure 2‐1 SLD of Newfoundland System ...................................................................................................................... 6

Figure 2‐2 Example Line Layout ..................................................................................................................................... 8

Figure 2‐3 Detailed Line Model ..................................................................................................................................... 9

Figure 2‐4 T1 ‐ SSD T5 ‐ WAV ....................................................................................................................................... 10

Figure 2‐5 Sunny Side T1 transformer model .............................................................................................................. 11

Figure 2‐6 SSD T1 Parameters ..................................................................................................................................... 12

Figure 4‐1 PSCAD Simulation ....................................................................................................................................... 15

Figure 4‐2 Actual Event ................................................................................................................................................ 15

Figure 4‐3 Transformer Currents ................................................................................................................................. 16

Figure 4‐4 Harmonics of Transformer (RMS) ............................................................................................................... 17

Figure 4‐5 Bay D'Espoir and TL237 measurements ..................................................................................................... 18

List of Tables

Table 2‐1 Frequency Dependent AC lines ...................................................................................................................... 7

Table 2‐2 SSD T5 ‐ WAV ............................................................................................................................................... 10

Table 2‐3 SCL Comparison ........................................................................................................................................... 12

Table 2‐4 Positive Sequence Impedance Comparison ................................................................................................. 13

Table 2‐5 Loadflow Comparison .................................................................................................................................. 13

Table 3‐1 AC system Fault Sequence ........................................................................................................................... 14

Table 3‐2 Internal Transformer Fault Sequence .......................................................................................................... 14




R1335.01.00 3 Oct 5th, 2014


1. Introduction

This report presents the findings of the PSCAD simulation trying to recreate the Newfoundland T1 transformer

fault that occurred at 9:05am on January 4th, 2014.

The original scope of the project was to model the fault based on delivered comtrade data which records the

pertinent waveforms. Upon receipt of the data, the following was noticed:

1. The comtrade data delivered for times:

04/01/2014,13:13:09.000260

04/01/2014,10:05:34.000260

Both of which did not match the time of the fault. The comtrade data which had the same time stamp as the

fault was delivered as a pdf file, which is included in Appendix A.

2. The comtrade data had a very low resolution as shown in Figure 1‐1, which made it very hard to match to the

PSCAD simulation.

Figure 1-1 Example of Low resolution Waveforms

APSCAD model was created on the following information in order to try and recreate the fault based on the pdf

comtrade file.

2014Base‐Peak for Dyr.sav

PSS/E data file which represents the Newfoundland System conditions prior to the fault

Peak Case.dyr

PSS/E dynamics file

SSDTS T1 transformer nameplate, test data and transformer data (delivered as pdf files)

WAVTS T5 transformer nameplate, test data and transformer data (delivered as pdf files)

-100

-50

0

50

100

10 15 20 25 30

SSTSCF1C>1_A-230 KV TL202 A Phase Voltage(V)

Electrotek Concepts® TOP, The Output Processor®

Magnitude (

Mag

)

Time (ms)




R1335.01.00 4 Oct 5th, 2014


AC Line geometric data based on past work performed by TGS. This included mutual coupling of

the lines the shared the same right‐of‐way.

AMEC report “Newfoundland and Labrador Hydro Transmission Availability” March 21, 2014.

This report gave the details of the sequence of events during the fault on January 4th.




R1335.01.00 5 Oct 5th, 2014


2. PSCAD Model Development

2.1 AC System model

The following files provided by Newfoundland and Labrador Hydro (NLH) and were used as the base case to

develop the equivalent PSCAD model:

2014Base‐Peak for Dyr.sav

Peak Case. Dyr

The equivalent ac system in PSSE was converted to PSCAD. Since this study deals with a transient phenomenon as

a result of transformer failure at Sunnyside, the representation of the power system components with more

accuracy at higher frequencies than the fundamental frequency is crucial for a better analysis of the event.

Therefore the following changes were made to the converted case:

All the generators were represented with their associated dynamic data. That includes also

exciter, governor and power system stabilizers models (PSS)

A majority of the transmission lines surrounding the Sunnyside and Western Avalon were

modeled with frequency dependent line models according to the tower geometries and

conductor configurations

T1 transformer at Sunnyside and T5 transformer at Western Avalon based on the latest data

provided by NLH

Figure 2‐1 shows the single line diagram of the ac system used in this study. Please note that the whole case is not

shown in the diagram and only the main portion of the ac system surrounding Sunnyside and Western Avalon is

shown.




R1335.01.00 6 Oct 5th, 2014


Figure 2-1 SLD of Newfoundland System




R1335.01.00 7 Oct 5th, 2014


2.2 AC Transmission Lines

The major transmission line models in the PSCAD case which when originally converted from PSS/E, were

represented as pi‐sections and Bergeron line models

The Bergeron and pi‐section line representations are only adequate for studies that essentially require the correct

fundamental frequency impedance. However, in order to get a higher degree of accuracy, some of the lines near

the affected buses were replaced with frequency dependent line models.

Table 2‐1 lists of the lines that were modeled as frequency dependent lines.

Table 2-1 Frequency Dependent AC lines

From Bus# To Bus# From Bus# To Bus#

195229 195230 195167 195169

195222 195227 195169 195171

195221 195216 195171 195173

195216 195215 195173 195175

195221 195220 195222 195229

195220 195218 195227 195229

195215 195208 195229 195236

195215 195205 195229 195234

195205 195536 195234 195236

195205 195208 195236 195238

195622 195625 195221 195222

195625 195627 195152 195153

195124 195122 195153 195154

195122 195120 195155 195157

195120 195115 195157 195159

195115 195112 195152 195159

195112 195111 195620 195620

195209 195210 195621 195622

195208 195209 195112 195113

195205 195206 195600 196500

195500 195620 ‐ ‐




R1335.01.00 8 Oct 5th, 2014


Figure 2‐2 shows an example of one of the more complicated line layouts, which includes the mutual coupling of

lines TL201, TL242 and TL218 and the mutual coupling of lines TL201 and TL217. Figure 2‐3 shows the detailed line

model for the lines TL201, TL242 and TL218.

Figure 2-2 Example Line Layout

N1

N2

N3

236

229

N4

234

238

SECTIO

NPI

2 CIRCUIT

1.0e-3 [ohm]

TL_201_218_242_1

TL201

TL242

TL_201_218_242_1

1

TL218

TL201

TL242

TL_201_218_242_1

1

TL218

1.0e-3 [ohm]

1.0e-3 [ohm]

TL_2490_229_1_1

1.0e-3 [ohm]

1.0e-3 [ohm]

1.0e-3 [ohm]

1.0e-3 [ohm]

TL201/T

L217

COU

PLED

PISECT

ION

COU

PLED

PISECT

ION

COU

PLED

PISECT

ION

1.0e-3 [ohm]

P = 260.6

Q =

12.79

V A

P = 166.1

Q =

-33.09

V A

P = 113.5

Q =

-59.98

V A

P = -185.2

Q =

-61.51

V A

P = -205.7

Q =

-68.45

V A

P = 111.8

Q =

-59.01

V A

P = 105.2

Q =

5.469

V A

P = 183.8

Q =

55.21

V A

==

=T

l218

==

=T

l242

==

=T

l217

P = -162

Q =

43.28

V A

==

=SZ

==

=SZ

==

=SZ




R1335.01.00 9 Oct 5th, 2014


Figure 2-3 Detailed Line Model

2.3 Power Transformers

The power transformer models T5 at Sunny Side and T1 at Western Avalon are updated based on the following

data files received from NLH:

“WAVTS T5 nameplate.pdf”

“WAVTS T5 Test Report.pdf”

“Western Avalon‐T5.pdf”

“Sunnyside‐T1.pdf”

“SSDTS T1 Nameplate.pdf”

“SSDTS T1 test report.pdf”

2000.0 [ohm*m]Resistivity:

Analytical Approximation (Wedepohl)Analytical Approximation (Deri-Semlyen)Aerial:

Underground:Mutual: Analytical Approximation (LUCCA)

20Max. Order per Delay Grp. for Prop. Func.:

20Maximum Order of Fitting for Yc:

1.0E6 [Hz]Curve Fitting End Frequency:Curve Fitting Starting Frequency: 0.5 [Hz]

Frequency Dependent (Phase) Model Options

Maximum Fitt ing Error for Yc: 1.0 [%]

1.0 [%]Maximum Fitt ing Error for Prop. Func.:

Travel Time Interpolation:

100Total Number of Frequency Increments:

On

DisabledDC Correction:Passivity Checking: Disabled

12.57 [m]

6.7056 [m]

C1 C2 C3

Conductors: Grosbeak

Tower: TL201

0 [m]

G1

5 [m]

Ground_Wires: 1/2"HighStrengthSteel

21.6834 [m]

6.858 [m]

C4 C5 C6

Conductors: 804

Tower: TL242

-35.847 [m]

G1

5 [m]

Ground_Wires: 1/2"HighStrengthSteel 13.53 [m]

5.18 [m]

C7 C8 C9

Conductors: Plover

Tower: TL218

31.27 [m]

G1

5 [m]

Ground_Wires: 1/2"HighStrengthSteel




R1335.01.00 10 Oct 5th, 2014


2.4 T5 Transformer at Sunny Side and T1 Transformer at Western Avalon

The T5 transformer at Sunnyside and the T1 transformer at Western Avalon is modeled based on the data

provided by NLH. Figure 2‐4 shows the PSCAD mode and Table 2‐2 shows the data used to model the

transformers.

Figure 2-4 T1 - SSD T5 – WAV

Table 2-2 SSD T5 - WAV

Name Tmva f YD1 YD2 YD3

T5 75 [MVA] 60.0 [Hz] Y Delta Y

T1 75.0 [MVA] 60.0 [Hz] Y Delta Y

Name Lead Xl12 Xl13 Xl23 Ideal

T5 Lags 0.1796 [pu] 0.0563 [pu] 0.1347[pu] Yes

T1 Lags 0.19677 [pu] 0.05578

[pu]

0.11371 [pu] Yes

Name NLL CuL Tap V1 V2

T5 0.000533 [pu] 0.00123335[pu] #1 230.0 [kV] 6.9

[kV]

T1 0.00057867 [pu] 0.00149133 [pu] #1 230 [kV] 6.9

[kV]

Name V3 Enab Sat Hys

T5 138.0 [kV] Yes Middle Jiles_Atherton

T1 138 [kV] Yes Middle Jiles_Atherton

1.0e6 [ohm]

#1

75 [MVA]230.0 [kV]/6.9 [kV]/138.0 [kV]

#3

#21.0e6 [ohm]

1.0e6 [ohm]

0.95

0.9625

1e-3 [ohm]

mid delta tert iary w inding is grounded. refer to xfr name plate

InT4_HInT4_L

#1

75.0 [MVA]230 [kV]/6.9 [kV]/138 [kV]

#3

#2




R1335.01.00 11 Oct 5th, 2014


2.4.1.1 Sunny side Transformer Model Internal Fault Modeling

The T1 transformer model was modeled such that various internal faults can be applied to the transformer. Figure

2‐5 shows the T1 transformer model that was used to investigate a failure of the a‐phase winding to ground (short

to the tank) and a failure between the windings. Figure 2‐6 shows the SSD T1 parameters.

Figure 2-5 Sunny Side T1 Transformer Model

#2

#3

Tap

#1

A

B

C

N

B

A

C

N

N3

N1

Tap

G1G2

N2

Tap

Tap

Tap

#2

#3

Tap

#1

#2

#3

Tap

#1

Faulta1

+

R1

Ia

Ib

Ic #2

#3

Tap

#1

+

R1Faulta




R1335.01.00 12 Oct 5th, 2014


Figure 2-6 SSD T1 Parameters

2.5 PSCAD Model Benchmarking Against PSS/E

Upon development of the ac network in PSCAD based on the equivalent developed model in PSS/E, it is required to

validate the PSCAD case against the equivalent case in PSSE. The validation was performed through comparison of

the short circuit levels at certain buses and the results of the load flow and power transfer at some selected

transmission lines.

The results of the comparison are shown in Table 2‐3, Table 2‐4 and Table 2‐5. The results compare very well

Table 2-3 SCL Comparison

Bus

Bus

Number

SCL (MVA)

% difference PSS/E Equivalent PSCAD

Western Avalon 195229 1997.30 1996.23 0.05

Sunny side 195222 2520.80 2469.65 2.03

Bay D Espoir 195221 2058.97 2014.47 2.16

Hollyrood 195234 2052.30 1998.49 2.62

Stony Brook 195216 3738.80 3601.09 3.68

Oxen Pond 195238 2164.00 2088.43 3.49




R1335.01.00 13 Oct 5th, 2014


Table 2-4 Positive Sequence Impedance Comparison

Bus Bus

Number

Positive Impedance magnitude

Z+(Ohm)

Positive Impedance angle

Z+(degree)

PSS/E

Equivalent

PSCAD %

difference

PSS/E

Equivalent

PSCAD %

difference

Western Avalon 195229 26.75 26.5 0.93 66.83 66.52 0.46

Sunnyside 195222 21.62 21.42 0.93 70.4 70.23 0.24

Bay D Espoir 195221 26.51 26.26 0.94 69.71 69.79 ‐0.11

Hollyrood 195234 26.8 26.47 1.23 70.87 70.98 ‐0.16

Stony Brook 195216 14.79 14.69 0.68 82.73 82.66 0.08

Oxen Pond 195238 25.39 25.33 0.24 78.77 78.68 0.11

Table 2-5 Loadflow Comparison

From

Bus

Number

To Bus

Number

Line Real Power (MW) Reactive Power (MVAR)

PSS/E

Equivalent

PSCAD %

difference

PSS/E

Equivalent

PSCAD %

difference

195229 195234 TL217 109.5 113.1 ‐3.29% ‐60.5 ‐59.72 1.29%

195236 TL201 165.7 166.2 ‐0.30% ‐33.4 ‐33.06 1.02%

195222 TL203 ‐213.8 ‐216.3 ‐1.17% 56.8 56.1 1.23%

195227 TL237 ‐184.8 187.2 ‐1.30% 31 30.19 2.61%

195222 195227 TL207 214.1 217.1 ‐1.40% ‐110.2 ‐109.3 0.82%

195221 TL206 ‐272.0 ‐275.8 ‐1.40% 54.9 53.58 2.40%

195221 TL202 ‐273.3 ‐275.8 ‐0.91% 56 53.59 4.30%

195221 195216 TL204 57.4 55.28 3.69% ‐5.0 ‐5.3 ‐6.00%

195216 TL231 57.6 55.28 4.03% ‐5.0 ‐5.3 ‐6.00%

195220 TL234 ‐115 ‐114.6 0.35% ‐15.9 ‐16.68 ‐4.91%




R1335.01.00 14 Oct 5th, 2014


3. Modeling of Fault

The modeling of the fault sequence was based on the AMEC report “Newfoundland and Labrador Hydro

Transmission Availability” March 21, 2014. The detailed sequence of events was given as shown Table 3‐1 below:

Table 3-1 AC System Fault Sequence Time delta‐T PSCAD Time event PSCAD Breaker Label

9:05:34.6 3.1

Fault Please see section 3.1

9:05:34.715 0.115 3.215 138kV Breaker L109T4 at SSD Opens CB1

9:05:34.753 0.038 3.253 138kV Breaker B3T4 at SSD Opens CB11

9:05:34.755 0.002 3.255 230kV Breaker B1L02 at SSD Opens CB2

9:05:34.786 0.031 3.286 138kV Breaker B2T1 at SSD Opens CB3

4 of 5 breakers for T1 now open, B1L03 does not open

9:05:36.719 1.933 5.219 Breaker L03L06 at SSD opens CB5

5.219 Breaker B1B2 at CBC Opens CB5

9:05:36.742 0.023 5.242 Breaker L03L06 at SSD opens CB6

9:05:36.820 0.078 5.32 Breaker L03L17 at WAV opens CB7

9:05:36.991 0.171 5.91 Breaker L01L03 at WAV opens CB8

3.1 Transformer Fault

In addition to the fault sequence modeled above, internal faults on the transformer were modeled. After various

faults were applied, Table 3‐2 shows the internal fault sequence that was found to give the closest results to the

transformer fault.

Table 3-2 Internal Transformer Fault Sequence PSCAD Time

event

3.1

Fault applied between phase A 230kV and 138 kV windings with a resistance of 50 ohms

3.15 Internal winding fault evolves into a 230kV to ground fault with a resistance of 50 ohms

3.2 Fault resistance decreases from 50 ohms to 25 ohms

4.0 A‐phase to ground fault evolves to a 3‐phase to ground fault with a resistance of 50 ohms

4.2 Resistance of 3‐phase faults decreases from 50 ohms to 25 ohms

4.7 Resistance of 3‐phase faults decreases from 50 ohms to 10 ohms




R1335.01.00 15 Oct 5th, 2014


4. Results

Appendix 2 shows the results for the fault. As it is unknown if this is the actual fault that was experienced by the

transformer, comparing values would not be useful. Of more use is comparing the trend. What is obvious right

away is that as breaker B1L03 did not open, the fault on the transformer was being sustained as shown in Figure

4‐1. Referring to Figure 4‐2, the neutral current in T1 extinguished before the breakers cleared the fault. Based on

the simulations, it seems more likely that the CT or the cabling was damaged during the event which led to a loss

of measurement.

Figure 4-1 PSCAD Simulation

Figure 4-2 Actual Event

Figure 4‐3shows the currents in the actual windings of the failed transformer during the fault.

Figure 4‐4shows the harmonics spectrum in the transformer during the fault.

x 0.00 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60

-2.00

-1.50

-1.00

-0.50

0.00

0.50

1.00

1.50

2.00

y

T1 High side Neutral Current

-2.00

-1.50

-1.00

-0.50

0.00

0.50

1.00

1.50

2.00

y





R1335.01.00 16 Oct 5th, 2014


Figure 4-3 Transformer Currents

x 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75

-1.25

1.25

y

Phase A 230kV Winding Current

-15.0 -10.0 -5.0 0.0 5.0

10.0 15.0

y

Phase A 6.9kV Winding Current

-1.50 -1.00 -0.50 0.00 0.50 1.00 1.50

y


-0.80 -0.60 -0.40 -0.20 0.00 0.20 0.40 0.60

y

Phase B 230kV Winding Current

-15.0 -10.0 -5.0 0.0 5.0

10.0 15.0

y

Phase B 6.9kV Winding Current

-0.60 -0.40 -0.20 0.00 0.20 0.40 0.60

y


-0.50

0.50

y

Phase C 230kV Winding Current

-15.0 -10.0 -5.0 0.0 5.0

10.0 15.0

y

Phase V 6.9kV Winding Current

-0 80-0.60 -0.40 -0.20 0.00 0.20 0.40 0.60

y





R1335.01.00 17 Oct 5th, 2014


Figure 4-4 Harmonics of Transformer (RMS)




R1335.01.00 18 Oct 5th, 2014


Figure 4‐5 shows the P, Q and speed of the Bay D’Espoir unit 1 and the current in line TL237 and the Western

Avalon bus voltage. As indicated in the AMEC report, and confirmed here, the ac system starts to go unstable for

this fault.

Figure 4-5 Bay D'Espoir and TL237 measurements

G_195001_0_1_DYR,Measure,P2 : Graphs

x 0.00 0.50 1.00 1.50 2.00 2.50 3.00

0.990

1.000

1.010

1.020

1.030

1.040

1.050

1.060

(pu

)

Wpu

-20

0

20

40

60

80

100

(M

W)

P

-60 -40 -20

0 20 40 60 80

100

(M

VAR)

Q

-2.00 -1.50 -1.00 -0.50 0.00 0.50 1.00 1.50 2.00

y

I237

-250 -200 -150 -100 -50

0 50

100 150 200 250

V_WA




R1335.01.00 19 Oct 5th, 2014


5. Conclusions and Recommendations

Although the exact fault has not been reproduced here, a fairly comparable one has been simulated. It is evident

that due to the long duration it took to clear the transformer fault, the transformer experienced very high

currents, with nearly 2.5kA flowing for the duration of the fault.

TGS recommendeds that once more details are available about the actual fault of the transformer, that the model

be updated and simulations rerun to recreate what happened. This new information will give further confidence in

the developed model and allow for future studies to be done either as a system strengthening exercise or for a

post‐mortem on future faults.




R1335.01.00 20 Oct 5th, 2014


6. Appendix 1 – Actual TFR Traces


Transcan DFR : SUNNYSIDE Terminal Station SSTSCF1C.X0V Jan/04/2014 09:05:34 (file)All Channels - 0X, 3840Hz Page 1 of 2

0.000 ms 1791.667 ms

202-Va202-Vb202-Vc202-Ia202-Ib202-Ic202-In203-Va203-Vb203-Vc203-Ia203-Ib203-Ic203-InT1-InT4-In206-Va206-Vb206-Vc206-Ia206-Ib206-Ic206-In207-Va207-Vb207-Vc207-Ia207-Ib207-IcB2-VaB2-VbB2-Vc94T186T1203-94A1203-94B1203-94C1203-94L1203-94L2203-P1P2


Transcan DFR : SUNNYSIDE Terminal Station SSTSCF1C.X0V Jan/04/2014 09:05:34 (file)All Channels - 0X, 3840Hz Page 2 of 2

Trace Label Name Scale Units/Division1 202-Va 230 KV TL202 A Phase Voltage 1.00 72177.652 V2 202-Vb 230 KV TL202 B Phase Voltage 1.00 72458.470 V3 202-Vc 230 KV TL202 C Phase Voltage 1.00 72601.507 V4 202-Ia TL202 A Phase Current 5.00 338.114 A5 202-Ib TL202 B Phase Current 5.00 338.290 A6 202-Ic TL202 C Phase Current 5.00 339.371 A7 202-In TL202 Neutral Current 15.00 113.019 A8 203-Va 230 KV TL203 A Phase Voltage 1.00 72423.934 V9 203-Vb 230 KV TL203 B Phase Voltage 1.00 72506.562 V

10 203-Vc 230 KV TL203 C Phase Voltage 1.00 72394.188 V11 203-Ia TL203 A Phase Current 5.00 337.960 A12 203-Ib TL203 B Phase Current 5.00 338.712 A13 203-Ic TL203 C Phase Current 5.00 338.641 A14 203-In TL203 Neutral Current 15.00 112.692 A15 T1-In T1 Neutral Current 2.00 1059.220 A16 T4-In T4 Neutral Current 2.00 1059.457 A17 206-Va 230KV TL206 A Phase Voltage 1.00 72296.314 V18 206-Vb 230KV TL206 B Phase Voltage 1.00 72600.926 V19 206-Vc 230KV TL206 C Phase Voltage 1.00 72753.172 V20 206-Ia TL206 A Phase Current 5.00 339.398 A21 206-Ib TL206 B Phase Current 5.00 338.909 A22 206-Ic TL206 C Phase Current 5.00 338.978 A23 206-In TL206 Neutral Current 15.00 113.283 A24 207-Va 230KV TL207 A Phase Voltage 1.00 72562.495 V25 207-Vb 230KV TL207 B Phase Voltage 1.00 72516.289 V26 207-Vc 230KV TL207 C Phase Voltage 1.00 72466.927 V27 207-Ia TL207 A Phase Current 5.00 339.563 A28 207-Ib TL207 B Phase Current 5.00 338.912 A29 207-Ic TL207 C Phase Current 5.00 340.012 A30 B2-Va 138 KV B2 A Phase Voltage 1.00 43573.561 V31 B2-Vb 138 KV B2 B Phase Voltage 1.00 43518.666 V32 B2-Vc 138 KV B2 C Phase Voltage 1.00 43444.008 V33 94T1 94T1 N/A N/A34 86T1 86T1(NC) N/A N/A35 203-94A1 TL203 94A1X N/A N/A36 203-94B1 TL203 94B1X N/A N/A37 203-94C1 TL203 94C1X N/A N/A38 203-94L1 TL203 94L1 N/A N/A39 203-94L2 TL203 94L2 N/A N/A40 203-P1P2 TL203 21P1/P2 N/A N/A




R1335.01.00 21 Oct 5th, 2014


7. Appendix 2 – Simulated Traces


Analog Graph

x 0.00 0.50 1.00 1.50 2.00 2.50 3.00

-300

-200

-100

0

100

200

300 y

V202:1

-500 -400 -300 -200 -100

0 100 200 300 400

y

V202:2

-400 -300 -200 -100

0 100 200 300 400

y

V202:3

-2.50 -2.00 -1.50 -1.00 -0.50 0.00 0.50 1.00 1.50 2.00 2.50

y

I202:1

-2.50 -2.00 -1.50 -1.00 -0.50 0.00 0.50 1.00 1.50 2.00 2.50

y

I202:2

-3.0

-2.0

-1.0

0.0

1.0

2.0

3.0

y

I202:3

-200 -150 -100

-50 0

50 100 150 200

y

V203:1

-250 -200 -150 -100

-50 0

50 100 150 200 250

y

V203:2

-200 -150 -100

-50 0

50 100 150 200

y

V203:3


Analog Graph

x 0.00 0.50 1.00 1.50 2.00 2.50 3.00

-4.0 -3.0 -2.0 -1.0 0.0 1.0 2.0 3.0

yI203:1

-3.0 -2.0 -1.0 0.0 1.0 2.0 3.0 4.0

y

I203:2

-3.0 -2.0 -1.0

0.0 1.0 2.0 3.0

y

I203:3

-2.00 -1.50 -1.00 -0.50 0.00 0.50 1.00 1.50 2.00

y


-2.00 -1.50 -1.00 -0.50 0.00 0.50 1.00 1.50 2.00

y


-300 -200 -100

0 100 200 300

y

V206:1

-500

400

y

V206:2

-400 -300 -200 -100

0 100 200 300 400

y

V206:3

-2.50

2.50

y

I206:1

-2.50

2.50

y

I206:2

-3.0 -2.0 -1.0 0.0 1.0 2.0 3.0

y

I206:3


Analog Graph

x 0.00 0.50 1.00 1.50 2.00 2.50 3.00

-300

-200

-100

0

100

200

300 y

V207:1

-500 -400 -300 -200 -100

0 100 200 300 400

y

V207:2

-400 -300 -200 -100

0 100 200 300 400

y

V207:3

-2.00 -1.50 -1.00 -0.50 0.00 0.50 1.00 1.50 2.00

y

I207:1

-2.00 -1.50 -1.00 -0.50 0.00 0.50 1.00 1.50 2.00

y

I207:2

-2.00 -1.50 -1.00 -0.50 0.00 0.50 1.00 1.50 2.00

y

I207:3

-5.0 -4.0 -3.0 -2.0 -1.0 0.0 1.0 2.0 3.0 4.0 5.0

y

SSD T1 phase A

-5.0 -4.0 -3.0 -2.0 -1.0 0.0 1.0 2.0 3.0 4.0 5.0

y

SSD T1 phase B

-5.0 -4.0 -3.0 -2.0 -1.0 0.0 1.0 2.0 3.0 4.0 5.0

y

SSD T1 phase C


x 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75

-1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 1.25

yPhase A 230kV Winding Current

-15.0

-10.0

-5.0

0.0

5.0

10.0

15.0

y

Phase A 6.9kV Winding Current

-1.50

-1.00

-0.50

0.00

0.50

1.00

1.50

y


-0.80 -0.60 -0.40 -0.20 0.00 0.20 0.40 0.60

y


-15.0

-10.0

-5.0

0.0

5.0

10.0

15.0

y

Phase B 6.9kV Winding Current

-0.60

-0.40

-0.20

0.00

0.20

0.40

0.60

y


-0.50 -0.40 -0.30 -0.20 -0.10 0.00 0.10 0.20 0.30 0.40

y


-15.0

-10.0

-5.0

0.0

5.0

10.0

15.0

y

Phase V 6.9kV Winding Current

-0.80 -0.60 -0.40 -0.20 0.00 0.20 0.40 0.60

y



Analog Graph

x 0.00 0.50 1.00 1.50 2.00 2.50 3.00

-0.06m

-0.04m

-0.02m

0.00

0.02m

0.04m

0.06my

Imaga

-2.00

-1.50

-1.00

-0.50

0.00

0.50

1.00

1.50

2.00

y

Fluxa

-0.35m

-0.30m

-0.25m

-0.20m

-0.15m

-0.10m

-0.05m

0.00

0.05m

0.10m

0.15m

y

Imagb

-2.00

-1.50

-1.00

-0.50

0.00

0.50

1.00

1.50

2.00

y

Fluxb

-0.3m

-0.2m

-0.1m

0.0

0.1m

0.2m

0.3m

y

Imagc

-2.00

-1.50

-1.00

-0.50

0.00

0.50

1.00

1.50

2.00

y

Fluxc


Analog Graph

x 0.00 0.50 1.00 1.50 2.00 2.50 3.00

0.00 0.50 1.00 1.50 2.00 2.50 3.00 3.50

yIT1_H_FFTa:1

0.00 0.10 0.20 0.30 0.40 0.50 0.60 0.70

y

IT1_H_FFTa:2

0.000 0.050 0.100 0.150 0.200 0.250 0.300 0.350 0.400

y

IT1_H_FFTa:3

0.000

0.050

0.100

0.150

0.200

y

IT1_H_FFTa:4

0.000

0.050

0.100

0.150

0.200

y

IT1_H_FFTa:5

0.000 0.025 0.050 0.075 0.100 0.125 0.150 0.175 0.200

y

IT1_H_FFTa:6

0.000 0.020 0.040 0.060 0.080 0.100 0.120 0.140

y

IT1_H_FFTa:7

0.000 0.020 0.040 0.060 0.080 0.100 0.120 0.140

y

IT1_H_FFTa:8

0.000

0.020

0.040

0.060

0.080

0.100

y

IT1_H_FFTa:9

0.000

0.020

0.040

0.060

0.080

0.100

y

IT1_H_FFTb:10


p r 11 hydro p.o. box 12400. st. john's. ni hydro place ... · documentation would be supplied...

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