System Loss Process and Results

7/29/2019 System Loss Process and Results

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Competency Training and Certification Program in Electric Power Distribution System Engineering

Certificate in

Power System Modeling and Analysis

T r a i n i n g Co u r s e i n

Sy s t em Lo s s A n a l y s i s


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2Training Course in System Loss Analysis

O u t l i n e

System Loss Segregation Process

Distribution System Data

Loss Segregation Results Single Feeder Analysis

Substation Analysis

Whole System Analysis

Technical Loss Summary

Distribution Transformer Losses Per DT Losses

DT Connected Loads

Bus Voltage

Line Current

Injected Current

System Loss Segregation Process
http://system%20loss%20segregation%20process.ppt/http://system%20loss%20segregation%20process.ppt/http://system%20loss%20segregation%20process.ppt/


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D i s t r i b u t i o n Sy s t em D a t a

From the gathered feeder data, well be ableto deduce important information of our

system which will serve as the brain of allthe activities of the EC.


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Distribution

System

Data

Operations

Data

Planning

Data

Design

Data

Financial

Data

Load

Data

Reliability

Data

Substation

Expansion

Program

Transformer

Load

Management

Capacitor

Al locat ion

Program

Tool

Economic

Cost Program

Power

Loss

Program

Protective

Device

Coordination

Primary

Voltage

Selection

Voltage

Profile and

Regulation


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The gathered data can be summarized

into a form such as the following:

T i i C i S L A l i


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ELECTRIC COOPERATIVE: NEA ELECTRIC COOPERATIVE

DATE: FEBRUARY 7, 2005

I. SUBSTATION

Location:

Capacity:Feeder No.:

II. PRIMARY LINES (KM)

3-phase:

2-phase:1-phase:

Phase A:

Phase B:

Phase C:

Total Circuit KM:

24.557

17.676

157.764

38

043.764

1.531

DISTRIBUTION SYSTEM DATA

METRO MANILA

1

7T i i C i S t L A l i


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III. DISTRIBUTION TRANSFORMERS (NO.)

1-phase:

10 kVA15 kVA

25 kVA

37.5 kVA

50 kVA

75 kVA

2-phase Bank:

2-10 kVA

2-15 kVA

2-25 kVA

2-37.5 kVA

3-phase Bank:

3-10 kVA

3-15 kVA

3-25 kVA

3-75 kVA

3-100 kVA

Total Number:

6439

45

2

0

0

1

0

2

1

2

1

1

0

0

170

8T i i C i S t L A l i


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IV. SECONDARY LINES (KM)

3-phase:

2-phase:

1-phase:

Phase A:

Phase B:

Phase C:

Total Circui t KM:

V. SERVICE DROPS (KM)

3-phase:

2-phase:1-phase:

Phase A:

Phase B:

Phase C:

Total Circui t KM:

0

0

95.758

18.621

40.198

36.939

95.758

0.207

0104.59

30.2655

37.4565

36.868

105.211



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VI. CUSTOMER DATA

Residential:

Commercial:

Industrial:

Public Building:

Street Lights:Total Number of Consumers:

534654

3790

552

56

203



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These data can be utilized by the ECfor the following purposes:

Asset Management

Various system studies such as

Load FlowShort CircuitReliabilityCapacitor Placement

Load ForecastingEtc.



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Lo s s Se g r e g a t i o n Re su l t s

AdministrativeLoss

+

Total Distribution

System Losses

=

Energy Deliveredto the Distribution

System

EnergyDelivered to

Users

-

Technical Loss Non-Technical Loss+

Bundled Technical & Non-Technical Losses



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Single Feeder Analysis

Total Energy Consumption

Input Metered Energy

Input Metered Energy Total Energy Consumption = Total Loss

Total Loss = Administrative Loss + Technical Loss + Non-Technical Loss

Percent Loss (%) = (Loss/Input Energy) x 100 %



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Training Course in System Loss Analysis


Single Feeder Analysis

SEGREGATED DISTRIBUTION SYSTEM LOSSES PER BILLING PERIODBilling Period: 30 days

Metered Input Energy(Kwh): 781799 100.00%

Total Consumption(Kwh): 594140.3 76.00%

Total Losses(Kwh): 187658.7 24.00%Administrati ve Losses(Kw h): 0.0001 0.00%

Technical Losses(Kwh): 31296.98 4.00%

Non-Technical Losses(Kwh): 156361.7 20.00%

NOTE:Losses must be with respect to the metered input energy and not on the

computed input energy



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Training Course in System Loss Analysis


Substation Analysis

F1

F2

F3

NOTE:For Substation Analysis, we are required to have the purchased eFor Substation Analysis, we are required to have the purchased energy fornergy forthe whole substation.the whole substation.



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g y y


Substation Analysis

F1

F2

F3

Feeder No.

Metered Input

Energy (kWhr)

Total Consumption

(kWhr)

Total Losses

(kWhr)

Percent Loss

(per feeder)

1 781,799.00 594,140.30 121,343.00 15.52

2 568,230.00 345,612.00 88,942.00 15.65

3 358,154.00 295,751.00 62,403.00 17.42



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g y y


Substation Analysis

P e r Fe e d e r V a l u e s :

Feeder No.

Metered Input

Energy (kWhr)

Total Consumption

(kWhr)

Total Losses

(kWhr)

Percent Loss

(per feeder)

1 781,799.00 594,140.30 121,343.00 15.52

2 568,230.00 345,612.00 88,942.00 15.653 358,154.00 295,751.00 62,403.00 17.42

Pe r Fe e d e r Co n t r i b u t i o n t o Su b s t a t i o n L o s s :

Feeder Loss Contribution =

Feeder Loss (kwhr)

Substation Energy

Purchased (kwhr)

X 100 %



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g y y


Substation Analysis

Pe r Fe e d e r Co n t r i b u t i o n t o Su b s t a t i o n L o s s :

2,000,000.00

FeederTotal Losses

(kWhr)Percent Loss(Substation)

1 121,343.00 6.07

2 88,942.00 4.45

3 62,403.00 3.12

Total Substation Loss: 272,688.00 13.63

Energy Purchased:



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Pe r Fe e d e r Co n t r i b u t i o n t o To t a l Sy s t e m Lo s s :

Feeder Loss Contribution =

Feeder Loss (kwhr)

System EnergyPurchased (kwhr)

X 100 %



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Pe r Fe e d e r Co n t r i b u t i o n t o To t a l Sy s t e m Lo s s :

15,000,000.00

Feeder

Total Losses

(kWhr)

Percent Loss

(Whole System)1 121,343.00 0.81

2 88,942.00 0.59

3 62,403.00 0.42

Substation Loss Contribution: 272,688.00 1.82

Energy Purchased:



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Te c h n i ca l Lo s s Re s u l t

Technical Losses SummarySEGREGATED DISTRIBUTION SYSTEM LOSSES SUMMARY

Name of Distribution Utility: NEA ELECTRIC COOPERATIVE, INC. (NECI)Substation/Feeder: NEA FEEDER

Technical Losses: kWHr/day kWHr/month %loss (Computed Energy Input):

Sub-transmission Line Loss 0.00 0.00 0

S/S Power Transformer Load Loss 0.00 0.00 0

S/S power Transformer No-Load Loss 0.00 0.00 0

Primary Distribution Line Loss 408.34 12,250.19 3.256605

Primary Service Drop Loss 0.00 0.00 0

Distribution Transformer Load Loss 41.52 1,245.49 0.331103

Distribution Transformer No-Load Loss 300.41 9,012.24 2.395825

Secondary Distribution Line Loss 148.09 4,442.65 1.18104

Secondary Service Drop Loss 13.29 398.63 0.105972

Voltage Regulator Loss 0.00 0.00 0

Shunt Capacitor Loss 0.63 18.90 0.005024

Shunt Inductor Loss 0.00 0.00 0

Series Inductor Loss 0.00 0.00 0

TOTAL 912.27 27,368.10 7.275569



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Te c h n i ca l Lo s s Re s u l t

TimeInput

(kWhr)

Input

(kVarhr)

STL

Loss

SSL

Loss

SSNL

Loss

PDL

Loss

PSD

Loss

DTL

Loss

DTNL

Loss

SDL

Loss

SSD

Loss

VR

Loss

ShuntCap

Loss

Shunt

L Loss

Series

L LossTOTAL

Hour 1 340.43 -320.80 0.00 0.00 0.00 9.24 0.00 0.49 12.52 1.70 0.12 0.00 0.03 0.00 0.00 24.07

Hour 2 235.92 -385.45 0.00 0.00 0.00 8.84 0.00 0.21 12.52 0.66 0.08 0.00 0.03 0.00 0.00 22.30

Hour 3 247.03 -378.59 0.00 0.00 0.00 8.83 0.00 0.24 12.52 0.74 0.09 0.00 0.03 0.00 0.00 22.41

Hour 4 252.61 -375.16 0.00 0.00 0.00 8.83 0.00 0.25 12.52 0.78 0.11 0.00 0.03 0.00 0.00 22.49

Hour 5 290.23 -351.88 0.00 0.00 0.00 8.94 0.00 0.34 12.52 1.07 0.20 0.00 0.03 0.00 0.00 23.06Hour 6 286.46 -354.21 0.00 0.00 0.00 8.93 0.00 0.32 12.52 1.05 0.21 0.00 0.03 0.00 0.00 23.03

Hour 7 285.53 -354.83 0.00 0.00 0.00 8.93 0.00 0.33 12.52 1.10 0.25 0.00 0.03 0.00 0.00 23.12

Hour 8 340.92 -320.52 0.00 0.00 0.00 9.41 0.00 0.58 12.52 1.83 0.55 0.00 0.03 0.00 0.00 24.89

Hour 9 483.02 -232.41 0.00 0.00 0.00 11.70 0.00 1.11 12.52 3.48 0.89 0.00 0.03 0.00 0.00 29.69

Hour 10 535.32 -199.85 0.00 0.00 0.00 13.03 0.00 1.24 12.52 4.01 0.95 0.00 0.03 0.00 0.00 31.75

Hour 11 445.78 -255.50 0.00 0.00 0.00 10.88 0.00 0.90 12.52 2.80 0.70 0.00 0.03 0.00 0.00 27.79

Hour 12 340.07 -321.12 0.00 0.00 0.00 9.35 0.00 0.60 12.52 1.78 0.47 0.00 0.03 0.00 0.00 24.72

Hour 13 462.54 -245.16 0.00 0.00 0.00 11.17 0.00 1.01 12.52 3.15 0.71 0.00 0.03 0.00 0.00 28.55Hour 14 569.49 -178.79 0.00 0.00 0.00 13.97 0.00 1.43 12.52 4.70 0.68 0.00 0.03 0.00 0.00 33.30

Hour 15 560.92 -184.09 0.00 0.00 0.00 13.76 0.00 1.35 12.52 4.49 0.70 0.00 0.03 0.00 0.00 32.81

Hour 16 355.04 -311.84 0.00 0.00 0.00 9.46 0.00 0.61 12.52 1.83 0.43 0.00 0.03 0.00 0.00 24.85

Hour 17 353.25 -312.90 0.00 0.00 0.00 9.41 0.00 0.61 12.52 1.84 0.32 0.00 0.03 0.00 0.00 24.69

Hour 18 971.88 71.91 0.00 0.00 0.00 35.35 0.00 4.63 12.52 16.73 0.93 0.00 0.03 0.00 0.00 70.16

Hour 19 1225.48 230.55 0.00 0.00 0.00 58.33 0.00 7.63 12.52 28.50 1.50 0.00 0.03 0.00 0.00 108.47

Hour 20 1152.18 184.63 0.00 0.00 0.00 51.07 0.00 6.74 12.52 25.21 1.30 0.00 0.03 0.00 0.00 96.83

Hour 21 1005.38 92.80 0.00 0.00 0.00 38.45 0.00 5.13 12.52 19.12 0.98 0.00 0.03 0.00 0.00 76.20

Hour 22 831.35 -15.82 0.00 0.00 0.00 26.63 0.00 3.55 12.52 13.40 0.68 0.00 0.03 0.00 0.00 56.77

Hour 23 550.09 -190.79 0.00 0.00 0.00 13.51 0.00 1.45 12.52 5.28 0.28 0.00 0.03 0.00 0.00 33.04

Hour 24 417.88 -272.82 0.00 0.00 0.00 10.31 0.00 0.80 12.52 2.86 0.17 0.00 0.03 0.00 0.00 26.64

TOTAL (D) 12538.81 -4982.64 0 0 0 408.3 0 41.516 300.408 148.1 13.288 0 0.63 0 0 912.27 Kwhr/day

%loss (Computed Energy Input): 0 0 0 3.257 0 0.3311 2.39583 1.181 0.106 0 0.005024 0 0 7.27557 %

%loss(Total Technical Loss): 0 0 0 44.76 0 4.5509 32.9297 16.23 1.4565 0 0.069059 0 0 100 %



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Te c h n i ca l Lo s se s Re s u l t

Applications:

Accurate determination of parts with most

contribution to system loss

Prioritization of parts for rehabilitation

Prioritization of EC projects



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D i s t r i b u t i o n T r a n s f o r m e r Re su l t s

Aside from the segregated losses, wecan also derive results regarding thedistribution transformers such as,

Individual DT Loss Contribution

Per DT Connected Loads



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I n d i v i d u a l D T Lo s s Co n t r i b u t i o n

Original

DT idTem p ID Input (P) Input (Q) DT Loss SL Loss SD Loss

Total

Loss%loss

PF100185 45 349.5856 215.9323 3.277111 7.593481 0.770966 11.64156 0.092844

PF100075 19 105.5128 62.95621 0.819976 9.291262 0.134986 10.24622 0.081716

PF100340 81 242.0961 148.0836 1.076315 7.240506 0.412663 8.729484 0.06962

PF100245 58 229.433 140.8264 0.966737 7.287583 0.111998 8.366317 0.066723

PF100345 82 244.2055 150.8682 1.108032 3.90392 0.635527 5.647479 0.04504

PF100465 110 112.9945 68.45472 0.615433 3.31905 1.560047 5.494529 0.04382

PF100750 177 106.3827 64.77823 0.818989 4.474203 0.056174 5.349365 0.042662

PF100475 112 134.2884 82.8069 0.63426 4.219335 0.231833 5.085428 0.040557PF100265 63 165.8797 102.5633 0.767601 4.013387 0.065331 4.846319 0.038651

PF100230 54 133.7607 81.98298 0.519322 3.817239 0.157511 4.494072 0.035841

PF100330 78 202.1513 125.0064 1.021052 3.109807 0.28713 4.417988 0.035234

PF100285 68 177.0064 109.3467 0.605511 3.43675 0.130776 4.173037 0.033281

PF100090 23 135.0403 82.76405 0.51878 3.469163 0.101724 4.089667 0.032616PF100360 85 126.6402 77.62619 0.559663 3.397153 0.116717 4.073533 0.032487

PF100660 158 160.6173 98.76873 0.829825 3.001078 0.119734 3.950637 0.031507

PF100260 62 196.0926 121.3271 0.872961 2.331464 0.088178 3.292603 0.026259

PF100315 75 144.3248 88.68076 0.569161 1.643298 0.879037 3.091496 0.024655

PF100350 83 130.3975 80.17073 0.436114 2.544045 0.050625 3.030783 0.024171



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A p p l i c a t i o n

From these results, well be able toaccurately determine which of theDTs contribute/s large amount of lossto the system.

This will prevent much loss to thecoop since based on our experience,most of the losses in the system are

in the distribution transformers.



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A p p l i c a t i o n

Prioritization of which DT to replacewill be more effective by using theseresults.



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Pe r D T Co n n e c t e d Lo a d s

DT From

Bus ID

Phase A

(real)

Phase A

(imag)

Phase B

(real)

Phase B

(imag)

Phase C

(real)

Phase C

(imag)

Total

(real)

Total

(imag)PF100185 349.58558 215.932 0 0 0 0 349.59 215.93

PF100345 1.108032 0.72687 0 0 243.0975 150.1413 244.21 150.87

PF100340 242.09614 148.084 0 0 0 0 242.1 148.08

PF100245 0.966737 0.63418 228.4663 140.1922 0 0 229.43 140.83

PF100275 217.60679 134.818 0 0 0 0 217.61 134.82PF100330 1.021052 0.66981 0 0 201.1303 124.3366 202.15 125.01

PF100305 66.824556 41.8749 66.94238 41.4995 66.94253 41.49917 200.71 124.87

PF100260 0.872961 0.57266 0 0 195.2197 120.7545 196.09 121.33

PF100300 1.047499 0.72801 192.5562 118.8679 0 0 193.6 119.6

PF100285 0.605511 0.39722 176.4009 108.9495 0 0 177.01 109.35PF100255 0.568537 0.37296 170.6222 105.7182 0 0 171.19 106.09

PF100265 0.767601 0.50355 0 0 165.1121 102.0598 165.88 102.56

PF100295 164.53093 101.518 0 0 0 0 164.53 101.52

PF100420 160.91545 99.4452 0 0 0 0 160.92 99.445

P and Q Loads of Each DT in KWH



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B u s V o l t a g e P r o f i l e

Also, voltages at various parts of thesystem can also be determined fromthe results.



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Voltage Prof ile At Hour 1

1 0 1 -119.9997 1 119.9997

PF200005 0.999431 -0.04781 0.999516 -120.0398 0.999285 119.9549

PF200010 0.999208 -0.066537 0.999326 -120.0555 0.999006 119.9373

PF200015 0.99901 -0.082588 0.999163 -120.0694 0.998783 119.9224

PF200020 0.998891 -0.09236 0.999068 -120.0778 0.998647 119.9134

PF200023 0.998663 -0.111063 0.998885 -120.0938 0.998388 119.8962

PF200025 0.998582 -0.118981 0.998846 -120.1018 0.998358 119.8893

PF200030 0.998397 -0.137796 0.998791 -120.1199 0.99828 119.8738

PF200033 0.998286 -0.149089 0.998758 -120.1308 0.998233 119.8645

PF200035 0.998278 -0.149056 0.99875 -120.1308 0.998226 119.8645

PF200040 0.998169 -0.161808 0.998729 -120.1431 0.998189 119.854

PF200045 0.997956 -0.186838 0.998667 -120.1673 0.998102 119.8329

PF200050 0.997892 -0.194058 0.998649 -120.1744 0.998084 119.8268

PF200055 0.99857 -0.113469 0.998706 -120.0905 0.998026 119.8921

PF200057 0.998543 -0.114513 0.998673 -120.0893 0.997915 119.8911PF200060 0 0 0.998669 -120.0893 0 0

PF200063 0.99845 -0.11833 0.998567 -120.0848 0.997523 119.8875

PF200065 0 0 0 0 0.997497 119.8874

PF200070 0.998433 -0.118859 0.99855 -120.0843 0.997471 119.887

PF200075 0.998433 -0.11881 0.998547 -120.0843 0.997471 119.887

Phase B

Magnitude

Phase B

Angle

Phase C

Magnitude

Phase C

AngleOrig ID

Phase A

Magnitude

Phase A

Angle



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Voltage Profile At Hour 19

PF200855 0.898139 -1.933083 0 0 0 0

PF200850 0.898186 -1.932807 0 0 0 0

PF200870 0.898376 -1.931373 0.912927 -122.0784 0.919784 118.3745PF200875 0.898376 -1.931373 0.912927 -122.0784 0.919784 118.3745

PF200857 0.898401 -1.930995 0.91292 -122.0782 0.919784 118.374

PF200847 0.898424 -1.931506 0.912957 -122.0774 0.919773 118.374

PF200840 0.898454 -1.936262 0 0 0 0

PF200845 0.898655 -1.934134 0.913204 -122.071 0.919692 118.3723

PF200837 0.89872 -1.934963 0.913278 -122.0691 0.919669 118.3719PF200835 0.898936 -1.935317 0.913401 -122.0647 0.919623 118.3694

PF200825 0.899045 -1.92673 0.91299 -122.0686 0.919687 118.3637

PF200820 0.899056 -1.927753 0.913056 -122.0678 0.919681 118.3643

PF200815 0.899084 -1.93387 0.913394 -122.0629 0.91961 118.3669

PF200813 0.899099 -1.935616 0.913495 -122.0613 0.919589 118.3676

PF200810 0.89916 -1.936371 0.913564 -122.0596 0.919569 118.3672PF200805 0.899314 -1.937544 0.913701 -122.0558 0.919529 118.366

PF200800 0.899428 -1.937982 0.91378 -122.0533 0.919505 118.3648

PF200795 0.899874 -1.939695 0.914091 -122.0435 0.919409 118.3604

PF200790 0.89997 -1.938952 0 0 0 0

PF200785 0.900028 -1.938633 0 0 0 0

PF200780 0.900283 -1.937269 0.914221 -122.0359 0.919448 118.3561

Phase B

Magnitude

Phase B

Angle

Phase C

Magnitude

Phase C

AngleOrig ID

Phase A

Magnitude

Phase A

Angle



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A p p l i c a t i o n s

Computation of actual voltages

Example: Voltage in p.u. = 0.898

Then, the actual voltage is,

Actual Voltage = 0.898 x 13.2 kV

= 11.86 kV

Actual Voltage = Voltage (in pu) x Base Voltage



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Voltage Variation

As stated in PDC Chapter 3, the actual voltage

should not exceed +10% or -10% of the nominal

voltage, or should range from 90-110% of the

nominal voltage.

*Recommended 0.95 1.05 p.u.

(Nominal Voltage Actual Voltage)% Variation = X 100%

Nominal Voltage



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Voltage Profile At Hour 1Line-Line

Voltage

Line-Line

Voltage

Line-Line

Voltage

Voltage

Variation

Voltage

Variation

Voltage

Variation

AB/BA BC/CB CA/AC AB/BA BC/CB CA/AC

PF100010 13198.70 13198.98 13199.12 0.010 0.008 0.007

PF100015 13195.97 13196.74 13197.29 0.031 0.025 0.021

PF100020 13194.55 13195.64 13196.42 0.041 0.033 0.027

PF100025 13192.79 13194.17 13195.37 0.055 0.044 0.035

PF100030 13191.26 13192.91 13194.48 0.066 0.054 0.042

PF100035 13190.47 13192.27 13193.97 0.072 0.059 0.046

PF100038 13189.45 13191.45 13193.31 0.080 0.065 0.051

PF100045 13188.32 13190.54 13192.57 0.089 0.072 0.056

PF100050 13187.02 13189.39 13191.77 0.098 0.080 0.062

PF100055 13185.60 13188.02 13190.91 0.109 0.091 0.069

PF100537 13184.71 13166.61 13206.73 0.116 0.253 -0.051

PF100057 13184.18 13186.67 13189.99 0.120 0.101 0.076

PF100065 13182.94 13185.51 13189.21 0.129 0.110 0.082

PF100535 13182.57 13165.74 13203.14 0.132 0.260 -0.024

PF100540 13182.24 13162.83 13205.29 0.135 0.282 -0.040

Bus ID



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Voltage Profile At Hour 19Line-Line

Voltage

Line-Line

Voltage

Line-Line

Voltage

Voltage

Variation

Voltage

Variation

Voltage

VariationAB/BA BC/CB CA/AC AB/BA BC/CB CA/AC

PF100680 12236.47 12056.49 12246.16 7.299 8.663 7.226PF100660 12235.92 12055.89 12246.68 7.304 8.668 7.222

PF100665 12235.68 12055.62 12246.68 7.305 8.670 7.222

PF100670 12235.59 12055.51 12246.68 7.306 8.670 7.222

PF100687 12234.35 12053.75 12244.34 7.316 8.684 7.240

PF100690 12231.63 12050.53 12241.87 7.336 8.708 7.259

PF100705 12230.24 12049.17 12240.94 7.347 8.718 7.266PF100710 12229.70 12048.45 12240.62 7.351 8.724 7.268

PF100715 12226.69 12044.46 12238.87 7.374 8.754 7.281

PF100720 12223.04 12039.55 12236.53 7.401 8.791 7.299

PF100725 12212.27 12022.54 12230.09 7.483 8.920 7.348

PF100730 11530.00 11490.00 11540.00 12.652 12.955 12.576

PF100735 12206.57 12014.58 12227.96 7.526 8.980 7.364PF100750 12203.98 12010.02 12225.95 7.546 9.015 7.379

PF100795 12203.98 12010.02 12225.95 7.546 9.015 7.379

Bus ID

VIOLATION!!!



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Voltage Unbalance

(Average Voltage Actual Voltage)% Unbalance = X 100%

Average Voltage



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Voltage Unbalance%

unbalance

%

unbalance

%

unbalance

Phase A Phase B Phase C

1 0 0 0

0.999998 0 0 0

0.999919 0.002615 0.002409 0.005024

0.999748 0.007056 0.008581 0.015637

0.999662 0.010055 0.01207 0.0221250.999554 0.012265 0.017961 0.030226

0.999461 0.014196 0.023115 0.037311

0.999412 0.015654 0.024871 0.040525

0.999349 0.017623 0.02698 0.044604

0.999067 0 0 0

0.999278 0.019868 0.029196 0.049063

0.999196 0.020579 0.033516 0.054095

0.999104 0.020004 0.039611 0.059615

0.999011 0.019968 0.044306 0.064274

0.999644 0 0 0

0.998931 0.020051 0.048443 0.0684940.99887 0.020135 0.051609 0.071743

Average

Voltage



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L i n e Cu r r e n t s

Line Current At Hour 1

Phase A Phase A Phase B Phase B Phase C Phase C

Real Imag Real Imag Real Imag

0 5502 11.27804 3.328538 -1.912626 -10.75915 -8.396858 8.92848

5502 5503 11.27804 3.328538 -1.912626 -10.75915 -8.396858 8.92848

5503 5505 11.27804 3.328538 -1.912626 -10.75915 -8.393235 8.9065325505 5513 11.27804 3.328538 -1.912626 -10.75915 -8.404727 8.424703

5513 5522 11.27804 3.328538 -1.793979 -10.69288 -8.404727 8.424703

5522 5524 11.27804 3.328538 -1.791069 -10.68785 -8.404727 8.424703

5524 5525 9.066739 4.546316 0.682197 -9.445926 -8.527026 3.277849

5525 5542 9.066739 4.546316 1.352682 -9.082851 -8.527026 3.277849

5542 5544 9.066739 4.546316 1.352682 -9.082851 -8.524886 3.27079

5544 5545 0.326763 -0.193496 -0.337316 -0.174407 0.010554 0.367904

5544 5547 8.739976 4.739812 1.689998 -8.908444 -8.53544 2.902887

5547 5552 8.483096 4.897462 1.689998 -8.908444 -8.53544 2.902887

5552 5561 8.483096 4.897462 1.689998 -8.908444 -8.545774 2.516345

5524 5563 2.211297 -1.217778 -2.473266 -1.241926 0.122299 5.146854

5563 5571 2.211297 -1.217778 -1.745605 -0.84906 0.122299 5.146854

5571 5572 0 0 -0.097733 -0.054912 0 05571 5574 2.211297 -1.217778 -1.647872 -0.794147 0.122299 5.146854

5574 5575 0 0 0 0 0.017409 0.665267

5574 5584 2.211297 -1.217778 -1.647872 -0.794147 0.10489 4.481587

5584 5586 0.022592 -0.01236 -0.203164 -0.113672 -0.000581 0.025764

5584 5588 0.592289 -0.353539 0 0 0 0

5588 5592 0.262775 -0.1524 0 0 0 0

From To



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L i n e Cu r r e n t s

Line Current At Hour 19Phase A Phase A Phase B Phase B Phase C Phase C


0 5502 39.44432 -14.2506 -31.9508 -26.5471 -7.19891 43.72753

5502 5503 39.44432 -14.2506 -31.9508 -26.5471 -7.19891 43.72753

5503 5505 39.44432 -14.2506 -31.9508 -26.5471 -7.19671 43.66083

5505 5513 39.44432 -14.2506 -31.9508 -26.5471 -7.26075 41.69974

5513 5522 39.44432 -14.2506 -31.469 -26.2849 -7.26075 41.69974

5522 5524 39.44432 -14.2506 -31.4661 -26.2799 -7.26075 41.69974

5524 5525 31.81121 -9.76329 -22.5763 -21.7246 -7.73228 26.51308

5525 5542 31.81121 -9.76329 -19.7134 -20.1913 -7.73228 26.51308

5542 5544 31.81121 -9.76329 -19.7134 -20.1913 -7.73011 26.5066

5544 5545 0.418715 -0.24701 -0.43297 -0.22101 0.014252 0.468024

5544 5547 31.3925 -9.51628 -19.2804 -19.9703 -7.74436 26.03858

5547 5552 30.38345 -8.88498 -19.2804 -19.9703 -7.74436 26.03858

5552 5561 30.38345 -8.88498 -19.2804 -19.9703 -7.79794 24.51131

5524 5563 7.63311 -4.48726 -8.88978 -4.55526 0.471528 15.18666

5563 5571 7.63311 -4.48726 -5.83146 -2.93344 0.471528 15.186665571 5572 0 0 -0.40487 -0.21873 0 0

5571 5574 7.63311 -4.48726 -5.42659 -2.71471 0.471528 15.18666

5574 5575 0 0 0 0 0.076236 2.504165

5574 5584 7.63311 -4.48726 -5.42659 -2.71471 0.395293 12.68249

5584 5586 0.085868 -0.05177 -0.82164 -0.44357 0.002026 0.100379

From To



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Current Unbalance:Phase A Phase A Phase B Phase B Phase C Phase C Branch Current Phase A Phase B Phase C

Mag (A) Arg(deg) Mag (A) Arg(deg) Mag (A) Arg(deg)Average (A)

%

Unbalance

%

Unbalance

% Unbalance

0 42.9737 0 -78.07898 0 165.0533 0 2.37 3.25 0.88PF100001 PF100005 0.11659 -30.27887 0 0 0 0 0.12 0 0 0PF100001 PF100010 19.94539 43.29441 21.12923 -78.07898 20.28447 165.0533 20.45 2.48 3.31 0.82PF100010 PF100015 19.87781 43.98318 21.12923 -78.07898 20.28447 165.0533 20.43 2.71 3.42 0.71PF100015 PF100020 19.87781 43.98318 21.12923 -78.07898 20.16462 166.0524 20.39 2.51 3.62 1.11PF100020 PF100025 19.7577 45.37103 21.12923 -78.07898 20.16462 166.0524 20.35 2.91 3.83 0.91PF100025 PF100030 19.74775 45.46315 21.11738 -77.99462 20.15505 166.143 20.34 2.91 3.82 0.91

PF100030 PF100035 19.74775 45.46315 20.93891 -76.2513 20.15505 166.143 20.28 2.63 3.25 0.62PF100035 PF100038 19.74775 45.46315 20.91451 -76.03094 20.15505 166.143 20.27 2.59 3.17 0.58PF100038 PF100040 0 0 0.055542 -147.8935 0 0 0.06 0 0 0

From To



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Line Loading

Phase A Phase B Phase C

% loading % loading % loading

PF100001 PF100005 220 0.05 0 0PF100001 PF100010 310 6.43 6.82 6.54PF100010 PF100015 310 6.41 6.82 6.54PF100015 PF100020 310 6.41 6.82 6.5

PF100020 PF100025 310 6.37 6.82 6.5PF100025 PF100030 310 6.37 6.81 6.5PF100030 PF100035 310 6.37 6.75 6.5PF100035 PF100038 310 6.37 6.75 6.5PF100038 PF100040 220 0 0.03 0PF100038 PF100045 310 6.37 6.74 6.5PF100045 PF100050 310 6.33 6.74 6.5PF100050 PF100055 310 6.31 6.74 6.5PF100055 PF100057 310 6.31 6.71 6.5PF100057 PF100060 220 0 0 0.02PF100057 PF100065 310 6.31 6.71 6.5

PF100065 PF100067 310 6.31 6.71 6.5PF100067 PF100070 220 0 0 0.38

From To Rating



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Cu r r e n t I n j e c t i o n s

Phase A Phase A Phase B Phase B Phase C Phase C


PF100005 0.0044 0 0 0 0 0

PF100010 0.007601 -0.000004 0 0 0 0PF100015 0 0 0 0 -0.028927 0.050278

PF100020 0.007703 -0.000016 0 0 0 0

PF100025 0.004002 -0.000011 -0.002012 -0.00346 -0.001991 0.00347

PF100030 0 0 -0.003726 -0.0064 0 0PF100035 0 0 -0.002923 -0.005015 0 0

PF100038 0 0 0 0 0 0

PF100040 0 0 -0.002925 -0.005014 0 0

PF100045 0.007607 -0.000037 0 0 0 0

PF100050 0.007608 -0.000042 0 0 0 0

PF100055 0 0 -0.003849 -0.006565 0 0

PF100057 0 0 0 0 0 0

PF100060 0 0 0 0 -0.002865 0.005045

Orig. ID

Competency Training and Certification Program in Electric Power Distribution System Engineering


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Th a n k y o u .

System Loss Process and Results

Documents

Transcript of System Loss Process and Results