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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/7/29/2019 System Loss Process and Results
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3Training Course in System Loss Analysis
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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4Training Course in System Loss Analysis
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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5Training Course in System Loss Analysis
D i s t r i b u t i o n Sy s t em D a t a
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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6Training Course in System Loss Analysis
D i s t r i b u t i o n Sy s t em D a t a
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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7Training Course in System Loss Analysis
D i s t r i b u t i o n Sy s t em D a t a
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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8Training Course in System Loss Analysis
D i s t r i b u t i o n Sy s t em D a t a
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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9Training Course in System Loss Analysis
D i s t r i b u t i o n Sy s t em D a t a
VI. CUSTOMER DATA
Residential:
Commercial:
Industrial:
Public Building:
Street Lights:Total Number of Consumers:
534654
3790
552
56
203
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10Training Course in System Loss Analysis
D i s t r i b u t i o n Sy s t em D a t a
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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11Training Course in System Loss Analysis
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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12Training Course in System Loss Analysis
Lo s s Se g r e g a t i o n Re su l t s
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
Lo s s Se g r e g a t i o n Re su l t s
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
Lo s s Se g r e g a t i o n Re su l t s
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
Lo s s Se g r e g a t i o n Re su l t s
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
Lo s s Se g r e g a t i o n Re su l t s
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
Lo s s Se g r e g a t i o n Re su l t s
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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Lo s s Se g r e g a t i o n Re su l t s
Whole System Analysis
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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Lo s s Se g r e g a t i o n Re su l t s
Whole System Analysis
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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B u s V o l t a g e P r o f i l e
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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B u s V o l t a g e P r o f i l e
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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A p p l i c a t i o n s
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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A p p l i c a t i o n s
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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A p p l i c a t i o n s
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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A p p l i c a t i o n s
Voltage Unbalance
(Average Voltage Actual Voltage)% Unbalance = X 100%
Average Voltage
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A p p l i c a t i o n s
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
Real Imag Real Imag Real Imag
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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A p p l i c a t i o n s
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
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A p p l i c a t i o n s
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
Real Imag Real Imag Real Imag
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 .