Commercial Presentation A Case of PQ Monitoring System of ...

19th Annual PQSynergyTM

International Conference and Exhibition 2019

Commercial Presentation

Terence Chandler

General ManagerDranetz Asia, Dranetz Corporation

Mr. Chandler has more than 30 years experience in the Power Quality Industry. He has published more than 100 papers on the various aspects of Power Quality, conducted 100's of classes and seminars on Power Quality.

A Case of PQ Monitoring System of a Very Large Utility in New York City

Power Quality Monitoring Systemat the Consolidated Edison Company of New York

© 2015 Electrotek Concepts, Inc. All rights reserved.

The Consolidated Edison Companyof New York

• Provide electrical service to New York City and Westchester County

• 3.3 million electric customers

• System Peak Load: 13189 MW

• 62 Distribution Substations

• 83 Secondary Networks and Non-Network Load Pockets

• 2247 Distribution Feeders

• 87% of Distribution System is Underground


Power Quality Monitoring System (PQMS)at the Consolidated Edison Company of New York

•Data Integration and Basic Analysis

•Permanent Faults

•Inrush Events

•Second Faults

•Incipient Faults

•SCADA/PQ System Federation


Con Edison Area Substation Monitoring

• All area substations have at least one PQ monitor. Some substations have two or more transformers monitored.

• Digital relay integration is much less extensive.

138 kV

13.8 kV

DistributionFeeders

NetworkCustomers

PQ Monitor

Digital Relay

Digital Relay

Digital Relay

SCADA RTUs: kV, A, kW, kvar, kVA, PF, tap position, voltage control mode, cap operations for transformer and/or feeders

Dranetz DataNode 5530 Monitors

PQViewDatabases

PQView

MicrosoftSQL Server

HTTP via RAS

Dranetz DataNode 61000 Monitors

InfoNode Servers

Proprietary Dialup PQNodeData FilesDranetz PQNode 8010

Monitors

InfoNode Servers

InfoNode Servers

MMS via WAN

File Share

HTTPvia LAN

LAN

Schneider Electric ION Meters

HTTP via Frame Relay

ION Server

EnerVista Download ServerSEL and GE Relays COMTRADE

Files

FileShare

HTTPvia LAN

HTTPvia LAN

ECC PI ServerSCADA RTU Sensors

PI SDK

LAN

Frame Relay

GE XA/21


Examples of Derivations Possible from Waveform Events using Con Edison PQMS

-100

-50

0

50

100

-500

0

500

-0.10 -0.05 0 0.05 0.10 0.15 0.20 0.25 0.30 0.35

Substation ION 7700 - 2/1/2003 09:30:31.5377

Electrotek/EPRI PQView®

Vo

lta

ge

(%

)C

urr

en

t (A

)

Time (s)

Va Vb Vc Ia Ib Ic

103

104

105

106

107

380

400

420

-0.10 -0.05 0 0.05 0.10 0.15 0.20 0.25 0.30 0.35

Substation ION 7700 - 2/1/2003 09:02:54.1855 RMS


Vo

lta

ge

(%

)C

urr

en

t (A

)

Time (s)

Va Vb Vc Ia Ib Ic

-1000

-950

-900

-850

-800

-750

-700

-650

-600

-550

-500

-450

-0.1 0 0.1 0.2 0.3

Substation ION 7700 - 2/1/2003 09:30:31.5377Reactive Power


Re

activ

e P

ow

er

(kva

r)

Time (s)

Qa Qb Qc

0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

0 10 20 30 40 50 60

Substation ION 7700 - 2/1/2003 09:02:54.18551-Cycle FFT Va from -0.01735 to -0.0008137 s


RMS 104.9Fund 104.4DC 0.04575Max 108Min -113.6CF 1.532FF 1.110THD Fund 9.73%THD RMS 9.68%HRMS 10.16Phase Jump 2.380°

Vo

lta

ge

(%

)

Frequency (60 Hz Harmonic)

0

2

4

6

8

10

5

10

15

20

25

-0.10 -0.05 0 0.05 0.10 0.15 0.20 0.25 0.30 0.35

Substation ION 7700 - 2/1/2003 09:02:54.1855Total Harmonic Distortion


TH

D (%

)T

HD

(%

)

Time (s)

Va Vb Vc Ia Ib Ic


Derivations from Waveformand RMS Samples

• Reactance-to-Fault

• Radial Fault Location

• Spectrum Charts

– 1, 2, 3, 4, 5, 6, 10, and 12 Cycle Windows

• Phasors and Harmonic Phasors

• High-Pass Filter and Low-Pass Filter

• First Derivative , Second Derivative, Third Derivative, and Squared Value·Time

• Mean Values and RMS Values

• Load Resistance, Load Reactance, Load Impedance, and Load Impedance Angle

• Real Power, Reactive Power, Apparent Power, and Energy

• Delta Real Power, Reactive Power, Apparent Power, and Energy

• Characteristic Voltage

• Waveform Transformation

• Missing Voltage and Delta Current from First Cycle or from Ideal Waveform

• Symmetrical Components

• Delta Symmetrical Components

• Three-Phase Diode Rectifier Output

• Line Frequency during Event

• Total Harmonic Distortion (THD)

• DC Component, Fundamental Component, and Harmonic Trends during Event

• Links to Map Viewer and Trend Viewer

• IEEE P1159.2 RMS Characteristics

• IEEE P1159.2 Point-in Wave Characteristics

• IEEE P1159.2 Missing Voltage Characteristics

• Dranetz Event Characteristics

• Digital Status Changes

• Operations Summary


RMS Voltage Variation Analysis

Total Events: 47Events Violating ITIC Lower Curve: 14Events Violating ITIC Upper Curve: 0

0.0

0.2

0.4

0.6

0.8

1.0

1.2

1.4

1.6

1.8

2.0

10-3 10-2 10-1 100 101 102 103

RMS Variation Magnitude-Duration Scatter PlotSelected Sites, From 2/1/2003 To 3/1/2003


Site Name

Service Entrance 3100Service Entrance 5530Service Entrance 5540Service Entrance 5571Service Entrance 7100Service Entrance 7700Substation 3720Substation 5530Substation 7700Substation 8010Substation DFR

Volta

ge M

agn

itude

(pu)

Duration (s)

0

10

20

30

40

50

60

1997 1998 1999 2000 2001 2002 2003

SARFI Rates by MonthSingle Site, From 1/1/1996 To 1/1/2003


Events

per

30 D

ays

Month

SARFI-90 SARFI-85 SARFI-70 SARFI-50

0

2

4

6

8

10

1996 1997 1998 1999 2000 2001 2002

SARFI Rates by YearSelected Sites, From 1/1/1996 To 1/1/2003


SA

RF

I-IT

IC -

Events

per

365 D

ays

Year

< 1 cyc1 cyc2 cyc3 cyc4 cyc5 cyc

6 to 10 cyc

10 to 20 cyc

20 to 30 cyc

30 to 60 cyc

1 to 2 sec

2 to 5 sec

5 to 10 sec

10 to 30 sec

30 to 60 se

c

60 to 1

20 sec

> 120 s

ecDuration

0.0

0.2

0.4

0.6

Events

per

Site p

er

30 D

ays

0 to 5

5 to 10

10 to 15

15 to 20

20 to 25

25 to 30

30 to 35

35 to 40

40 to 45

45 to 50

50 to 55

55 to 60

60 to 65

65 to 70

70 to 75

75 to 80

80 to 85

85 to 90

Voltage

Mag

nitu

de (%

)

Sag and Interruption Rate Magnitude-Duration Column ChartSelected Sites, From 2/1/2003 To 3/1/2003



Analysis of Data Logs

5.5

6.0

6.5

7.0

1 SatFeb 2003

8 Sat 15 Sat 22 Sat 1 Sat

Substation - V RMS A, V RMS B, V RMS Cfrom 2/1/2003 to 3/1/2003

EPRI/Electrotek PQView®

Time

Min[V RMS A] (kV) Avg[V RMS A] (kV) Max[V RMS A] (kV) Min[V RMS B] (kV) Avg[V RMS B] (kV)

Max[V RMS B] (kV) Min[V RMS C] (kV) Avg[V RMS C] (kV) Max[V RMS C] (kV)

0%

5%

10%

15%

20%

25%

30%

0%

20%

40%

60%

80%

100%

6.8 6.9 7.0 7.1 7.2

Substation - V RMS A, V RMS B, V RMS Cfrom 2/1/2003 to 3/1/2003

EPRI/Electrotek PQView®

Count 24183Min 6.785Avg 7.105Max 7.299Range 0.5141St Dev 0.08452CP01 6.826CP05 6.931CP25 7.068CP50 7.121CP75 7.162CP95 7.215CP99 7.244SI Range 0.04703

Rela

tive

Fre

qu

en

cy

Cum

ula

tive

Fre

qu

en

cy

Avg[V RMS A] (kV), Avg[V RMS B] (kV), Avg[V RMS C] (kV)

Relative Frequency Cumulative Frequency


Area SubstationTransformer

Primary Feeders Secondary Network

A

B

C

Single Line to Ground Fault

• PQ Monitors at Low Side of Many Area Substation Transformers

• Digital Relay Data Available at 20% of Primary Feeders


Example SLG Fault Recorded by PQ Monitor at Area Substation

• Fault type and fault start/stop detection algorithm based on waveforms, phasors, zero-sequence, negative-sequence, and spectral content.

1A

-1.0

-0.5

0

0.5

1.0

-2

0

2

4

0 0.05 0.10 0.15

SHERMN4N - 9/9/2012 18:59:01.6880I²t=28.85 kA²·s

Operation

Point Name SCBX54N.DX

Time Stamp 9/9/2012 18:59:05.0012

Value S_CREEK BKR 54N 1X23

Description CLOSE-TRIP

Voltage (

pu)

Curr

ent

(kA)

Time (s)

Va Vb Vc Ia Ib Ic


Example Correlation of Feeder RecloseEvent with PI Event from SCADA Operation

-10

-5

0

5

10

-2000

0

2000

0 2 4 6 8 10

50THST - 12/24/2010 22:25:48.3130

Electrotek/EPRI Reference Cycle = 4669 PQView®

Operation

Point Name 50BX41W.DXTime Stamp 12/24/2010 22:25:52.0059Value W50ST BKR 41W 5M90Description TRIP-CLOSE

Vo

ltag

e (

kV

)C

urr

ent

(A)

Time (c)

Va Vb Vc Ia Ib Ic


Example Correlations of Capacitor EnergizingEvent with PI Event from SCADA Operation

-10

-5

0

5

10

15

-3000

-2000

-1000

0

1000

2000

0 2 4 6 8 10

50THST - 12/22/2010 06:20:11.3130


Operation

Point Name 50BXC2.DXTime Stamp 12/22/2010 06:20:14.0116Value W50ST BKR C2 CAP_2Description TRIP-CLOSE

Vo

ltag

e (

kV

)C

urr

ent

(A)

Time (c)

Va Vb Vc Ia Ib Ic

-10

-5

0

5

10

-2000

-1000

0

1000

2000

0 2 4 6 8 10

50THST - 12/22/2010 06:35:17.1250


Operation

Point Name 50BXC1.DXTime Stamp 12/22/2010 06:35:20.0112Value W50ST BKR C1 CAP_1Description TRIP-CLOSE

Vo

ltag

e (

kV

)C

urr

ent

(A)

Time (c)

Va Vb Vc Ia Ib Ic


Event Categorization

Permanent Faults

•Single-Phase: A, B, C

•Two-Phase: AB, BC, CA

•Three Phase Faults: ABC

Subcycle Faults

•Single-Phase: A, B, C

•Two-Phase: AB, BC, CA

•Three Phase Faults: ABC

Feeder Inrush

•A, B, C, AB, BC, CA, ABC

Overcurrent

•Zero-Sequence: I0

•Negative-Sequence: I2– “Second Fault”

•Phase: IA IB, IC

Voltage Sag

•A, B, C, AB, BC, CA


Automatic E-Mail Notifications

• Inrush Events

Subject: Inrush Event Notification: Parkview TR4

Subject: Fault Notification: Parkview TR4

• Fault Events


Reactance-to-Fault Calculations for PQ Measurement at Area Substation

1A 0.7469 (k1=3.800)

0.8

1.0

1.2

0

1

2

1.0

1.5

2.0

0.02 0.04 0.06 0.08 0.10 0.12 0.14 0.16 0.18

SHERMN4N - 9/9/2012 18:59:01.6880Voltage, Current, and Reactance Values

Voltage (

pu)

Curr

ent

(kA)

React

ance

(Ω

)

Time (s)

Va Vb Vc V0 V1 V2 Ia Ib Ic XTF


Predicted Location of Fault by Matching Measured Reactance to Reactance of Circuit Model


Visualized Location of Fault


Distribution Fault Location Results

•On average, use of the reactance-to-fault method for fault location saves one hour per feeder restoration job

•Mitigates use of capacitive discharge thumpers and DC high voltage (hi-pot) testing

Year 0-1 MH 1-3 MH 3-5 MH 5-10 MH > 10 MH

2009 64% 24% 5% 2% 6%

2010 67% 14% 5% 3% 11%

2011 64% 20% 8% 3% 5%

Summer 2012 76% 14% 4% 4% 1%

Relay RTF Website


Transmission Feeder Trip - Email Notification

Station / Timestamp

All ChannelsMin/Max RMS Values


Transmission Feeder Trip - Email Notification

W72 Trip Out


Transmission Feeder Trip Notificationwith Maximum RMS Values


Fault Location Projects using the Same Power Quality Monitoring System at Con Edison (PQView)

Company Voltage (kV) Initiated Sensors CircuitModels

SCADAIntegration

Status

Con Edison Network Feeders 13, 27, 33 2005 PQ Monitorsand Relays

Proprietary OSIsoft PI System

Production

San Diego Gas & Electric 12 2006 PQ Monitors SynerGEE Pilot Completed

Wisconsin Public Service 25 2008 PQ Monitors SynerGEE Pilot Completed

United IlluminatingCompany

4.16, 13.2 2008 PQ Monitors CYMDIST Production

DTE Energy (Detroit Edison) 40 2009 PQ Monitors Custom OSIsoft PI System

Production

Georgia Power Network 12.47, 25 2019 Relays CYMDIST Preproduction

American Electric Power 13.2 2011 PQ Monitors CYMDIST Pilot Completed

Hydro-Québec 25 2012 PQ Monitors CYMDIST Pilot

Alabama Power Company 13.2 2012 PQ Monitors CYMDIST Oracle SOE Preproduction

Hydro Ottawa 13.2 2013 PQ Monitors CYMDIST OSIsoft PI System

Pilot

Con Edison Overhead 4.16 2013 PQ Monitors Proprietary Pilot

Tennessee Valley Authority 161 2013 DFRs CAPE Pilot

National Grid 13 kV 2015 RecloserControllers

CYMDIST Prepilot

British Columbia Hydro MV 2015 PQ Monitorsand Relays

CYMDIST OSIsoft PI System

Prepilot

Jamaica Public Service MV 2015 PQ Monitors CYMDIST Prepilot


What are the Other Data Sources for the Power Quality Monitoring Systems at Con Edison (PQView)?

• IEEE® PQDIF

• IEEE® COMTRADE

• MODBUS®

• Advantech®

• Arbiter® Systems

• BTECH®

• Cooper CYMDIST

• Dranetz®

• EDMI

• Electro Industries®

• ENTSO-E Loads

• Environment Canada

• Fluke®/RPM

• GE®

• Gossen Metrawatt

• I-Grid®

• GridSense

• HIOKI

• OSIsoft® PI System

• Power Monitors

• PSL PQube®

• Qualitrol® /LEM

• SATEC

• Schneider Electric®

• Schweitzer Engineering Laboratories®

• Siemens®

• SynerGEE® Electric

• TECTRA ALFA

• Unipower®

• Duke Energy Carolinas Oracle FMS




•Permanent Faults

•Inrush Events

•Second Faults

•Incipient Faults



CIOA Events

•A “cut-in open-auto” event (CIOA) describes a feeder trip immediately upon re-energization

•A CIOA could be caused by a fault or by inrush current

•Relays at area substations detect an overcurrent condition on the feeder and trip the breaker – even though there is no fault

•If there is no fault, the feeder can be re-energized quickly

•Con Edison needed automation to distinguish between fault events and inrush events reliably


Cut-In Open-Autos: Fault versus Inrush

-2000

-1500

-1000

-500

0

500

1000

1500

2000

0 0.02 0.04 0.06 0.08 0.10 0.12 0.14 0.16 0.18

WATERST - 5/16/2011 18:00:47.3130


Time (s)

Ia Ib Ic

-25000

-20000

-15000

-10000

-5000

0

5000

10000

15000

20000

25000

0 0.02 0.04 0.06 0.08 0.10 0.12 0.14 0.16 0.18

WATERST - 5/16/2011 18:00:47.3130


Time (s)

Va Vb Vc

Am

ps

Vo

lts

I NRUSH

-4000

-3000

-2000

-1000

0

1000

2000

3000

4000

0 0.02 0.04 0.06 0.08 0.10 0.12 0.14 0.16

Bensonhurst 1 TR3 - 10/8/2013 03:43:48.8100


Time (s)

Ia Ib Ic Ires

-25000

-20000

-15000

-10000

-5000

0

5000

10000

15000

20000

25000

0.02 0.04 0.06 0.08 0.10 0.12 0.14

Bensonhurst 1 TR3 - 10/8/2013 03:43:48.8100


Volta

ge (

V)

Time (s)

Va Vb Vc

Am

ps

Vo

lts

FAUL T


New Steps for Con Edison PQMS ModuleI²T Calculation and Analysis

1A

-10000

0

10000

-4000

-2000

0

2000

4000

0 0.05 0.10 0.15

Substation MonitorI²t=61.57 kA²·s


No Operations Found

Voltage (

V)

Curr

ent (A

)

Time (s)

Va Vb Vc Ia Ib Ic

1A I2

-20000

-10000

0

10000

20000

-5000

-0

5000

0 0.1 0.2 0.3

Substation MonitorI²t=60.60 kA²·s


Operation

Point Name 42BX42S.DX

Time Stamp 7/24/2014 23:25:43.0163

Value W42ST_1 BKR 42S 16M79

Description CLOSE-TRIP

Voltage (

V)

Curr

ent (A

)

Time (s)

Va Vb Vc Ia Ib Ic


“Second Faults”

•After a feeder is repaired a high voltage (hi-pot) test is performed

•Between 9/1/2010 – 9/1/2013 Manhattan, Brooklyn & Queens had 384 failed-on-test occurrences (FOTs)

892

648

457

154 141 890

100

200

300

400

500

600

700

800

900

1000

Manhattan Brooklyn Queens

Open-Auto

Failure-On-Test

16.51% 21.89%19.63%

9/1/2010 – 9/1/2013

9/1/2010 – 9/1/2013Brooklyn Queens

Total FOTs analyzed 114 65

Failed on the rise 88 40

Failed ammeter clear 19 21

Failed at test voltage 7 4

FOTs that failed on rise or ammeter clear

94% 94%


Single Line to Ground Fault

C

T

C

C

Area Substation Transformer

Primary Feeders Secondary Network

A

B

C

• Within seconds of the circuit breaker trip in the area substation due to the fault, network protectors are engineered to open and fully deenergize the primary feeder cable.

• If a network protector does not open, then there is an overvoltage on the unfaulted phases up to line-to-line voltage.

• This may cause a second fault on the out-of-service feeder that may not be in the same location as the first fault.


Capturing Waveforms during Second Faults and Sending Notifications

Secondary Network

•Two Voltage Sags Recorded by PQ Monitors at “Master Point”

•Only One SCADA Operation

Area Substations

•SLG Fault with Zero-Sequence

•Subsequent Negative-Sequence Overcurrent

•One SCADA OperationPQ Monitor Retrofitted

with Negative-Sequence Filter


Second Fault: Initial Fault Measuredat the Substation

– Rise in current with a sag in voltage

– Causes feeder to open automatically (OA)

Negative Seq / Current UnbalanceZero Seq / Ground Current


Second Fault: Subsequent Overcurrent Measured at Substation

• Subsequent Event– A Negative-Sequence Current Filter installed on the monitor triggers

when a current unbalance is detected to capture the event. – The presence of negative-sequence current with no zero-sequence

current indicates current is passing through a network transformer to a second fault.

Negative Seq / Current UnbalanceZero Seq / Ground Current


PQView sends an email notification after detecting a second fault and no operations.

Subject: Fault Notification: Plymouth ST TR4

Subject: Possible Second Fault Detected: Plymouth ST TR4

•Fault

•Second Fault

Second Fault E-mail Notification




•Permanent Faults

•Inrush Events

•Second Faults

•Incipient Faults



Incipient Fault Identification and Notification

-1.0

-0.5

0

0.5

1.0

-2

0

2

4

0.5 1.0 1.5 2.0 2.5

Multiple Subcycle Faults - Possible Precursor to Permanent Fault

Voltage (

pu)

Curr

ent

(kA)

Time (s)

Va Vb Vc Ia Ib Ic


Incipient Subcycle Fault LocationUsing Time-Domain Estimation

-1.0

-0.5

0

0.5

1.0

-3

-2

-1

0

0.35 0.40 0.45 0.50 0.55

Subcycle Incipient Fault

Voltage (

pu)

Curr

ent

(kA)

Time (s)

Va Vb Vc Ia Ib Ic

Estimated XTF: 0.3235 Ω

Actual XTF: 0.3221 Ω

-1.0

-0.5

0

0.5

1.0

-5

0

5

10

0.35 0.40 0.45 0.50 0.55 0.60 0.65 0.70 0.75

Subsequent Permanent Fault

Voltage (

pu)

Curr

ent

(kA)

Time (s)

Va Vb Vc Ia Ib Ic


Subcycle Fault with Breaker Operation

-1.0

-0.5

0

0.5

1.0

-6

-4

-2

0

0.40 0.45 0.50 0.55 0.60 0.65 0.70

Subcycle Fault Leads to Breaker OperationEstimate Reactance-to-Fault (XTF) = 0.1468 Ω Actual Reactance-to-Fault (XTF) = 0.1474 Ω

Voltage (

pu)

Curr

ent

(kA)

Time (s)

Va Vb Vc Ia Ib Ic




•Permanent Faults

•Inrush Events

•Second Faults

•Incipient Faults



Area Substation Voltage Control

•The amount of MW load determines what the voltage should be at the area substation following a set of rules called the “voltage schedule”.

– Whether the voltage can be above or below the scheduled voltage depends upong the time of day and the day of week

•Methods of Controlling Area Substation Voltage

– Voltage Var Control (VVC Mode)

– Local Tap Changer Control System (CMVM Mode)

– Manual Adjustment of Transformer Taps



Area Substation Load versus Voltage Schedule

13.2

13.3

13.4

13.5

13.6

150

200

250

9 Sat

Jul 2011

10 Sun 11 Mon 12 Tue 13 Wed 14 Thu 15 Fri 16 Sat

Station A

Con Edison® PQView®

kVM

W

Time

Scheduled Voltage Max Voltage Min Voltage HGLODWX


Con Edison PQMS Module: Voltage and Reactive Power Control Analysis



Voltage Control and Optimization

•Process Control Tool Development

– Control Variables

• Voltage Deviation from Schedule

• Range of Tap positions on Parallel Transformers

• Range of Mvar Load on Parallel Transformers

– Apply control chart methods to develop upper and lower control limits


Simple Application of Statistical Process Control Methods

• Early each Monday morning, derive weekly average and standard deviation values for the control variables

• At the same time, create weekly summary reports for distribution via e-mail and on the company intranet

• When analyzing a week for statistical process control, derive upper control limit (UCL) and lower control limits (LCL) value that compare the average and standard deviation for the past week to the average and standard deviations of the eight weeks prior to the past week.

analyzed being week The

Variable Controlled of Average Weekly

Variable Controlled of Average Weekly

8

...3

8

...

8

...3

8

...

821821

821821

n

StDev

Avg

StDevStDevStDevAvgAvgAvgLCL

StDevStDevStDevAvgAvgAvgUCL

nnnnnnn

nnnnnnn


VV

C

VVC

-MAN

MA

N-V

VC

VVC

-MAN

MA

N-V

VC

VVC

-MA

NM

AN-CM

VM

CM

VM

-MAN

MAN

-VVC

VV

C-C

MVM

CM

VM

-MA

N

MA

N-CM

VM

CM

VM

-VVC

VVC

-MAN

13.4

13.6

13.8

14.0

-200

0

200

100

150

200

5 SunJun 2011

6 Mon 7 Tue 8 Wed 9 Thu 10 Fri 11 Sat 12 Sun

Substation A


kVV

MW

Time

Station PI.LE1VOLT Scheduled Voltage Max Voltage M in Voltage

SCADA Voltage Deviation Voltage Deviation LCL Voltage Deviation UCL LE1LODWX

5.01% UCL-LCL

Voltage Deviation Control Chart

Process Control Violation


Tap Range Control Chart

13.0

13.2

13.4

13.6

-15

-10

-5

0

5

40

60

80

100

120

5 Sun

Jun 2011


Station C


kVTaps

MW

Time

Station PI.MHVOLT MHTT1.MX MHTT2.MX MHTT3.MX

MHTT4.MX Tap Range Tap Range UCL MHLODWX

UCL – 5 Taps


Reactive Power Balance Control Chart

13.3

13.4

13.5

13.6

40

50

60

70

0

1

2

3

4

5

6

5 SunJun 2011


Station D


kVM

WM

var

Time

Station PI.TCVOLT TCLODWX Mvar Range Mvar Range UCL

UCL – 4 MVARProcess Control

Violations


Power Factor Summary Weekly Report


Tap Changer Summary Weekly Report


Area SubstationVoltage Control Summary

• Regulation Control Mode Performance Across the Area Substation Population for One Week


What’s Next at Con Edison?Increased Data Integration Functions in PQView 4

SQLServers

PQ Monitors

PQView 4DMS

PQ & Energy Meters

DigitalRelays

PQ/DE PIServer

PQView 4API & Web

Services

IEC 61850 IEDs

Web and Mobile Applications

Desktop AppsOPC-DA Server

OPC-DA Clients

MODBUSSensors

IEEE PQDIF FilesIEEE COMTRADE Files

DE PIServer

ECC PIServer


What’s Next: Fault Locationin Overhead Distribution System

• New power quality monitors installed in Queens as part of the American Recovery and Reinvestment Act

– New monitors installed to complete a pilot project on overhead fault location with a primary goal to locate problem line sections or equipment after measuring momentary faults

• Radial feeder models from integrated from on company modeling software in 2013

• SCADA correlation added in January 2014

• Both resistance-to-fault and reactance-to-faultwill be explored

• The project includes display of the feedersusing aerial imagery with one-line feeder overlays


What’s Next for Area Substation for Fault Location

•New Firmware for Monitor to Compute/Trigger on Negative-Sequence Current internally

•Automation of Subcycle/Incipient Fault Location Estimation


For more information:

Brian Todd [email protected]

Kevin Kitteridge [email protected]

Commercial Presentation A Case of PQ Monitoring System of ...

Documents

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