Areva

François Lhomme 22.02.2005François Lhomme 22.02.2005

MiCOM P441, P442 & P444Distance Protection

Complet technical Overview = 180 Slides openedfrom a total of 345 slides

Lattes, February 2005

François LHOMMEMarketing Products


Presentation

Complet technical Overview = 180 Slides openedfrom a total of 345 slides ( in the middle of the bottom of each slide )


PROGRAM - J1 :

Date 15/3

AREVA EAI Presentation 09.00

MiCOM range: family, functions 10.15

MiCOM Px40: organisation HW & features 10.30

Algorithms, distance calculation 11.00

Coffee break 11.30

Algorithms, distance calculation ,phase sel,Direct 11.45

Lunch 12.45


Coffee break 15.30


Conclusion 17.15

Training courseDistance MICOM P444

PROGRAM - J2 :

Date 16/3 Algorithms, distance calculation ,phase sel,Direct 9.30

Coffee break 11.30


Lunch 12.45

Questions/Answers 14.00

Coffee break 15.30

Software versions description 15.45

MiCOM S1 - workshop 16.30

Conclusion 17.30


PROGRAM - J3 :

Date 17/3 MiCOM S1 - Application customer & Back-up fonctions 9.30

Coffee break 11.30

MiCOM S1 - Application customer & Back-up fonctions 11.45

Lunch 12.45

MiCOM S1 - Application customer & Back-up fonctions 14.00

Coffee break 15.30

MiCOM S1 - 15.45

Conclusion 17.30


PROGRAM - J 4 :

Date 18/3 Discussion: Questions/Answers 9.30

Coffee break 11.30

Conclusion 11.45

Lunch 12.45

Discussion: Questions/Answers 14.00

End of session 17.00


> MiCOM P441, P442, P444 - February 20058 8

BusinessOverview


Presentation Overview

Our Solution

Our Mission

Our Markets

Our Offer

Our Brands

Our Presence

Our Differentiators

Our Partnerships

Our Position

Our References


Our Solution to your Needs

Your ConcernThe efficient operation of your energy infrastructure and

markets in a reliable and secure environment

You NeedA business partner with proven technology, an integrated

automation offering and a local presence

We OfferAn innovative and complete range of products, systems and

support that is leading the market in a fast-evolving environment

Leader in Real-Time Energy InfrastructureLeader in Real-Time Energy Infrastructure


Our Mission

To be the leading worldwide provider of Energy Management Solutions through automation and information systems, industry-leading software, mission-critical equipment and services for the efficient, reliable and secure operation of energy infrastructure and markets

Reliable Solutions for A Secure InfrastructureReliable Solutions for A Secure Infrastructure


Our Market

Expertise in Your BusinessExpertise in Your Business


Our Complete Offer

Reliable Technology Reliable Technology


Our Brands

e-terraComplete suites of energy and market management software

PACiSComprehensive range of numerical, digital and conventional

substation automation systems

MiCOMSuite of high and medium voltage protection relays

BiTRONICSFull range of electrical measurement devices

Complementary Product FamiliesComplementary Product Families


Our Worldwide Presence

Seattle : Energy & Market Management Systems

San Jose : Energy Market Participants Bethlehem : Measurement & Metering Farnham : Energy Retail Settlements Lattes : Substation Control Systems Massy : Telecommunications

Stafford : Protection & Control (HV/MV)

Centers of Excellence 9 Manufacturing Centers

20 Engineering Centers

46 Service Centers & Remote Offices

Local Delivery Points

Ease of Doing BusinessEase of Doing Business


0

10

20

30

40

AREVA GE ABB Siemens Telvent OSI ACS

Best maintenance >1M customersBest technical approach >1M customersBest implementation schedule >1M customersBest value for money >1M customersBest overall performance >1M customersBest maintenance IOUsBest technical approach IOUsBest implementation schedule IOUsMost value for money IOUsBest overall performance IOUs

Our Differentiators

Source: Newton-Evans Research 10/2003

The Partner Who Delivers On Your NeedsThe Partner Who Delivers On Your Needs

Quality, Reliability& Support

Ease of Doing Business / Expertise Technology Reactivity to

New Needs


56%

64%

95%

0% 20% 40% 60% 80% 100%

Support

Systems

Products

Three Annual Users Groups on three continents North America Europe Australasia

Customers allocate a portion of R&D Hours

Strong installed customer base

Global Customer Agreements

Customer Partnerships

World Class Customer RelationshipsWorld Class Customer Relationships


Technology Partnerships


18 4396

550

1974 1984 1994 2004

N° 1 in Energy Market Systems

N° 2 in Protection Relays

5000 Clients

30 Million Euro Annual R&D Investment

12% Annual Growth since 1974

Leadership Positioning

The Reliability of a Worldwide Industry LeaderThe Reliability of a Worldwide Industry Leader


“The Automation Business Unit is your dedicated partner in bringing you the power of IT technology for the efficient and secure operations of your infrastructure”

Laurent Demortier,T&D Automation Executive Vice President


MiCOM Distance: History & People


The P441/P442/P444 Distance The « Protection Team! »

François Lhomme (Marktg)

Damien Tholomier(Marketing Director)

Laurence Barbe (Markg)

Thierry Bardou (R&D manager)

Patricia Morvan (R&D)

Denis Froment (R&D)

Fabrice Gilles (R&D)


Expertise in the Distance Protection field...

PXLN

EPAC 3000

EPAC 3800 LFZP

Legacy

PXLP (1980)Quadramho

Optimho

MiCOM P44x (Since 2001)


Technology evolution

Electro-mechanical

Mono-functionRelays

1940-1970

AnalogueMono-function

Relays

1970-1990

DigitalIntegrated

IED

1990-2000

DigitalIntegrated

CommunicatingIED

2000-2010

?

U

RI U=RI

U=XV+RW

Total 2001->2005 = More than 6000 relays!

The P441/442/444 MiCOM in the World



MiCOM range Presentation

LFZP141Generat

orProtecti

on


MiCOM Relays

MiCOM Products A complete range of protective relays, racks and cubicles for

all applications, integrated into a digital control system or stand-alone. MiCOM P Series : Protection Relays

MiCOM M Series : Measurement products for accurate metering

MiCOM C Series : Substation management products

MiCOM S Series : PC support Software and substation control Packages


MiCOM Relays Hardware & Software Platform

Platform

20 Series

30 Series

40 Series


MiCOM Protection Portfolio

P900 P900 Frequency Protection RelaysFrequency Protection Relays

P800 P800 Autoreclose, Breaker Fail ...Autoreclose, Breaker Fail ...

P100 P100 Feeder Management RelaysFeeder Management Relays

P700 P700 Busbar Protection SchemesBusbar Protection Schemes

P600 P600 Transformer Protection RelaysTransformer Protection Relays

P500 Line Differential and Unit SchemesP500 Line Differential and Unit Schemes

P400 P400 Distance Protection RelaysDistance Protection Relays

P300 P300 Generator Protection RelaysGenerator Protection Relays

P200 P200 Universal Motor Protection RelayUniversal Motor Protection Relay

P4xx = distance



20 Series

30 Series

Platform

40 Series

Feed

er P

rote

ctio

n

Dis

tanc

e Pr

oetc

tion

Gen

erat

or P

rote

ctio

n

Diff

eren

tial p

rote

ctio

n

Volta

ge /

Freq

uenc

y Pr

otec

tion

Tran

sfor

mer

pro

tect

ion

Mot

or P

rote

ctio

n



Feeder Feeder

Px40

Motor Motor GeneratorGenerator

P 14x P 24x

P 22x

P 94x

FrequencyFrequency

P 139

Px30

P 34x

P 12x P 92xP 22x

DistanceDistance

P 44x

P 43x

IIDiff.Diff.

P 54x

Px20

P 63x

Transf. Transf. Diff.Diff.

P 52x

B.B.B.B.Diff.Diff.

P 74x


MiCOM protections cover all areas of the power system

MiCOM Relays

P630

Generation

Transmission

Industry

Low Voltage

Distribution

Home

P120

P220P120

P240

P140

P140

P340 P940 P920

P540 P140P440

P630

P630

P340

P139

P139

P740


MiCOM Product Selectionfor Solidly/effectively-grounded

Systems


Design Pedigree:AREVA HV/EHV Distance

GGC

GG

G

G

G

T RIP

AL AR M

OU T OF S ER VIC E

H EAL THY

ED IT

= C LEAR

= EN TER

= R EAD

C

MiCOM

PXLN SHNBPD571

P439

P432 EHVONE-BOXSOLUTION

P441/P442/P444DISTANCE

PROTECTIONP443

MiCOMhoPROTECTION

P437 LFZPOptimho

LFZRLFDC

EPAC

Algos. Algos.Algos. Algos.

Algos. Algos.Ph/select

Algos. SOTF,Schemes

Algos.Control

∆ DirectionP44x/P54x H/W

µmho


Approximate Guidance:Speed

110/145kV

220/275kV

380/500kV

735/800kV

20/33kV

66/69kV

Trip SpeedP430

V

1.5 cyc. 1.25 cyc. 1 cyc.

P437

P441/P442/P444

P443

Main Protection

Backup Protection


Approximate Guidance:Characteristics

110/145kV

220/275kV

380/500kV

735/800kV

20/33kV

66/69kV

Trip SpeedP430

V

1.5 cyc. 1.25 cyc. 1 cyc.

P442 P437 P443

Mho and/or QuadrilateralPolygon / Quadrilateral

Polygon Quad

MhoQuad


MiCOM Distance Protection Characteristics Available

jX

R

Zs

Zn

MEMORY-POLARISEDMHO

QUADRILATERAL

OFFSETMHO

jX

Zn

Zn

R

P437

P443 P443P443

P443P442 P443 P437

Xfw X

βZfw,PPZfw,PG

Zfw

Zbw70°

RRfw,PGRfw,PP

POLYGONAL

X

R

ZArcZLineZone 2

Zone 3

MHO


P441/P442/P444 Summary

Universal distance protection - with a proven installed base

Versatile distance relay for all HV → EHV applications

Extremely secure - Delta techniques, for fault detection, directionality and phase selection

Patented algorithms used in 3 generations of numerical relays

Overhead line and /or cable applications (K01/KO2/KO3)

Efficient use of panel space - size 40TE (P441) or 60TE (P442) or 80TE (P444) / Different I/O capacity

Menu-driven software for setting and analysis

Intuitive setting

Common Px40 training modules

Comprehensive back up protection

P441/442/444


P437 Summary Distance protection for application up to and including the highest

system voltages

Design experience - 3rd generation of numerical distance protection from the same design team

Proven V<, I>> and shaped Z< starting for high sensitivity Z< starter acts as a load blinder, to ensure stability when no tripping is

wanted

Maintains and manages the stability of the grid Out of step tripping to control system separation

An ideal complement to P44x family relays in “dual-main” distance protection applications

Adjustable to any system grounding condition Integrated Bay Control available Wall mounting case available

Advanced protection and control in a Modular platform

P437

Xfw X

βZfw,PPZfw,PG

Zfw

Zbw70°

RRfw,PGRfw,PP


Z3 (reverse offset)

Zp (reverse)

P443 MiCOMho Summary

Mho and quadrilateral elements available within one device - line/cable type and length not needed at time of ordering

Load blinder avoids spurious or cascade tripping, without desensitising the protection

Selectable mho characteristic polarising permits control over expansion - allowing support for compensated and non-compensated applications

The relay self-sets zone reaches from protected line data - “simple setting mode”

Superimposed (∆I) fault and power swing detection requires no starters to be set

Easy to set and apply

SUB CYCLE Relay < 1 cycle!

High Speed Distance Protection Designed for Ease of Application

P443

P443


Typical HV/EHV Product Selection

Choose P44x family or P437 to give full-scheme relay performance.

Choose P441/P442 for a multifunction distance relay for general applications. Offers quadrilateral characteristics, with a proven installed base of products .Dedicated test tool (Zgraph) - commissioning mode

Choose P430C/P433/P435/P439 for applications in solidly/effectively grounded and isolated/Peterson coil compensated systems (distribution network).

Choose P432/P439 as one-box solutions where integrated bay control is required.

Choose P437 for high speed tripping on HV/EHV systems, where quadrilateral/polygon characteristics are preferred.

Choose P443 where guaranteed sub-cycle tripping is required (mho or quadrilateral), and in any mho characteristic applications.

Mix and match in dual main protection applications!

P442 P443 P437


Key Selling Points!

PSL = Graphical easy solution adapted to client application

Easy to set and apply (MiCOM S1- PSL - Zgraph - Monitor bit…)

Modular Capacity of I/O - Maxi = P444 offers 24 Inputs / 46 Outputs

SUB CYCLE Relay < 1 cycle!

Friendly tools: Event / Dist Rec-Fault report - Maintenance code

Universal Optos filtered or not (optionnal)

Fast Trip or static output contact (optionnal)

Stability during Pswing - Out Of step (Prevent black out!)

Multi port of communication

IEC 61850 coming soon

NCIT options (available in P441/2/4 for site trial)

Hot Keys in front panel

See P443

High Speed Distance Protection Designed for Ease of Application

P442 P443 P437


MiCOM P44x Series - Product SelectorType of Characteristic

Mho Quad Mho+Quad Don’t Care

Typical Operating TimeFast:

0.7 to 1 cycle(price premium)

General Purpose:0.8 to 1.25 cycle

Binary I/O Requirements

8in/14out 16in/21out 24in/32out 24in/46out

Hardware & Trip OptionsIs IRIG-B, ethernet, 2nd rear comms,

or single pole tripping required?

Binary I/O

16in/24out 24in/32out

YesNo

P442

P444..J P444..K

P443.A. P443.B.

P441

MiCOM P441, P442 & P444 Distance Protection

C2.x


P441/P442/P444 Summary

Universal distance protection - with a proven installed base

Versatile distance relay for all HV → EHV applications


Patented algorithms used in 3 generations of numerical relays(LFDC, PXLN, EPAC)

Designed for overhead line and /or cable applications (K01/KO2/KO3)

Efficient use of panel space - size 40TE (P441) or 60TE (P442) or 80TE (P444) / Different I/O capacity


Intuitive setting

Common Px40 training modules


P441/442/444


Overview of Protection Features

Directional Negative Phase Sequence (46)

Broken Conductor (46BC)

Channel Aided Trip Logic (Distance and Directional Earth Fault (85-21/85-67N)

Under & Over Voltage (59, 27)

Directional & Non Directional Phase and Earth Fault Overcurrent (50/51/67PN)

Breaker Failure (50BF)

Distance Protection (21)

Power Swing Blocking/Tripping (68)

Weak Infeed (27WI)

TOR/SOTF (50HS)

Thermal Overload ( 49)

Stub bus protection (50-Stub)


Overview of Operating Functions (1)

Setting Groups

VT / CT / CVT Supervision

Fault Locator

Auto Reclose & Check Synchronism

CB Control & Maintenance

Programmable Scheme Logic

More…

Trip Circuit Supervision (74TC) via PSL


Instrumentation

Post Fault Analysis

Communications

HMI Interface

Previous…

Self Diagnostics & Commissioning

Hardware Construction

Overview of Operating Functions (2)


Hardware Presentation MiCOM P440


From… to

First AREVA Shipments in October 2004


MiCOM Protection

P900 Frequency Relay

P800 Auto-reclose Relay, Fail CB

P100 MT Start Protection

P700 Busbar Differential Protection

P600 Differential Protection of Transformer

P500 Line or cable Differential Protection

P400 Distance Protection

P300 Generator Protection

P200 Motor Protection


Presentation Protection Functions

Distance Protection

4 Setting groups

Inverse directional Max I / Non Directional

Directional Max I / Non Directional

CB Fail

Auto-Reclosure & Voltage supervision

Teleaction Distance Schemes

DEF / PW / IN>


PresentationAdditional Functions

TC / TP / TCT Supervision

Faults Locator

Control & Supervision

(PSL) Logic Scheme Programmable

Conductor break pick up

Max U & Min U


PresentationAdditional Functions

Instrumentations

Fault analysis skills

Communications

Material

Interface Man/Machine

Diagnostic aid


Hardware Presentation MiCOM P440


Available ModelsP441 - Housing 8” (40TE)

Three-phase trip and auto-reclosure

8 opto-insulated inputs

14 output contacts 6 N/O 8 C/O

Option: Check Sync

Conventional Instrument Transformer or NCIT (IEC61850 - 9 - 2)



Three-phase and single phase trip and auto-reclosure


21 output contacts 9 N/O 12 C/O

Options: Voltage control - IRIG-B synchronization

Voltage control for Check Sync

IRIG-B synchronization

IEC60870 - 5 / 103 Optical Fibre Converter


Second rear communication port/InterMICOM/UCA2



Three-phase and single phase trip and auto-reclosure


32 (up to 46max-model H) output contacts 24 N/O 8 C/O

Options:

Voltage control for Check Sync

IRIG-B synchronization

IEC60870 - 5 / 103 Optical Fibre Converter


Second rear communication port/InterMiCOM/UCA2


Rated Values ofInputs/Outputs

Analogue Voltage transformers: Voltage: 80 - 140Vca ph-ph

Analogue Current tranformers: Dual CT inputs 1A/5A

Or Digital Acquisition for Non Conventional Instrument Transformers (Optical Fibre Input - IEC 61850 -9 - 2 protocol)

Auxiliary Voltage: 19 - 65 Vcc

37 - 150Vcc or 24 - 110Vca

87 - 300Vcc or 80 - 265Vca

Field voltage (for external use) : 48V DC(current limit: 112 mA)


8,16 or 24 opto universal inputs (24 - 250Vcc)

6N/O, 8C/O Outputs or 9N/O, 12C/O or 24N/O, 8C/O

Contact characteristics: Make and Carry: 30A during 3s

Carry continuous : 5A Breaking Capacity: 62.5W with L/R=40ms

Watchdog Contact 1N/O, 1N/C Breaking Capacity : 15W with L/R=40ms

Rated Values ofInputs/Outputs


Hardware Architecture (P441 & P442)

IRIG-B PCB (P442)

BNC Rx1 Tx1

Transformer PCB

4 VT, 4 TC

8 opto inputs & isolated &

Analogue PCB 16 bits ADC

Relay PCB

8 Outputs (P442)

8 Relay PCB

isolated inputs(P442)

PowerSupply

Relay PCB

8 Outputs

64-way ribbon cable (BUS)

Main processor & User interface(DSP TMS 320C33 150 MHz)

Battery SK2 SK1

Co-processor PCB(DSP TMS 320C33 150 MHz)

Second Com. port (P442)

BNC SK4 SK5Or

Relay PCB

8 Outputs

Backup Protection Disturbance Recorder Fixed Scheme Logic Programmable Scheme Logic Comm. and HMI Management

Samples acquisition Electronic Filtering Threshold calculation Distance Algorithms


Hardware Architecture (P444)

Transformer PCB

4 VT, 4 CT

8 opto inputs & Analogue PCB

16 Bits ADC

Power Supply PCB

Relay PCB 8 Outputcontacts

64-way ribbon cable (BUS)

Co-processor PCB(DSP TMS 320C33 150 MHz)

Opto input PCB

8 Inputs

Relay PCB 8 opto

inputs

Relay PCB 7 Output contacts

Relay PCB7 Outputcontacts

Relay PCB8 Output contacts

Relay PCB 8 OutputContacts

Relay PCB

8 Ouput contacts

Main processor and user interface PCB

(DSP TMS 320C33 150 MHz)

Battery SK2 SK1

Backup Protection Disturbance Recorder Fixed Scheme Logic Programmable Scheme Logic Comm. and HMI Management

Samples acquisition Electronic Filtering Threshold calculation Distance Algorithms

IRIG-B PCB (P442)

BNC Rx1 Tx1

Second Com. port (P442)

BNC SK4 SK5Or


MiCOM P444Hardware Description

MiCOM P444 - Front OpenedMiCOM P444 - Front Opened63

64 way ribbon cable

Front panel included Main Processor &

User Interface Board(MiCOM Px40 series standard)(MiCOM Px40 series standard)


MiCOM P444Hardware Description

MiCOM P444 - Position of the boards inside the caseMiCOM P444 - Position of the boards inside the case64

Power supply moduleincluded

one outputs board Optional IRIG-B Board

Co-processor BoardTransformer Module

3 Opto Universal Boards8 inputs per board24 inputs per P44424 inputs per P444

4 Output Boards8 OMRON relays per board

3232 outputs per P444 (24 n/o & 8 c/o) outputs per P444 (24 n/o & 8 c/o)+2 PCB 7relays = +2 PCB 7relays = 4646 outputs in H version outputs in H version


MiCOM P441-442-444Hardware Description

MiCOM P444 - Rear viewMiCOM P444 - Rear view65

Power supplyconnection

((Terminal blockTerminal block N) N)

1st Rear Communication port RS485

OptionalOptionalFibre optic connection

IEC60870-5-103(Not for P441)

1A / 5A current & voltageinput terminals((Terminal blockTerminal block C) C)

Option:Programmable digitaloutputs (2x7relays) connection

((Terminal blockTerminal block G & H) G & H)

Programmable digitaloutputs (32 relays) connection

((Terminal blockTerminal block J, K, L & M) J, K, L & M)

Programmable 24 digital inputs connection

((Terminal blockTerminal block D, E & F) D, E & F)

OptionalOptionalIRIG-B Board(Not for P441)

Others options:Others options:- ethernet- ethernet-2nd rear-2nd rear

-InterMicom-InterMicom(Not for P441)


P44x Existing Range - Version Compatibility

A2.6

A2.11

Hard refA

PSL ref 512 cells

A3.0

A3.3

A B

C1.0

C1.1

G - H - J

A4.0

A4.8

B1.0

B1.4

C

C2.x

PSL ref 1024 cells

04A06A06B

07A07B 09C

020G020H

030G030H030J

Areva


Addition of the Fault Location Cell in IEC60870-5/103 protocol Optional 2nd rear communication port (Courier protocol only):

Language: Courier always

Physical links:RS 232or RS 485 (polarity sensitive)or K-Bus (non polarity sensitive)

Second rear portCourier Port since A4.0

(RS232/RS485)

InterMiCOM (RS232) available since C1.0

IRIG-B

SK5

SK4

P44x??7????????? : 2nd rear port onlyP44x??8????????? : 2nd rear port and IRIGB

P44x Phase 2 DevelopmentLast Version A4.8 & more - Since August 2004


IRIG-B Board

Cortec selection:P44???x

(No options for P441)

MiCOM P442-444Hardware Description

(Options)

Rear view - Communications optionsRear view - Communications options68

Fibre optic connectionIEC60870-5-103

2nd rear portCourier

(RS232/RS485)

Inter-MiCom Port (RS232)

optical port

Copper port

Ethernet10/100MHz

1st Rear port

Cortec selection:P44?????x


Integration of the new CPU board at 150 MHz

Optional fast static outputs

Optional 46 outputs in P444-model 20H/ 30H

Addition of a settable time delay to prevent maloperation due to zone evolution from zone n to zone n-1 by CB operation

Addition of a tilt characteristic for zone 1 (independent setting for phase-to-ground and phase-to-phase). Settable between ± 45°

Addition of a tilt characteristic for zone 2 and zone P (common setting for phase-to-ground and phase-to-phase/Z2 and Zp). Settable between ± 45°

Additional DDB signal - Distance Earth Fault

Integration of special RTE weak infeed logic (PAP)

Integration of uncompressed disturbance recorder with resolution of 24 samples

Addition of Control input Buttons (“Hotkeys”)

Version C1.0 - available from April 2004Version C2.2 - available from Sept 2004

P44x Phase 2 Development


Integration of InterMiCOM (serial communication from relay to relay)

Addition of an independent Tp Transmission Time Delay for

Aided Trip Logic for DEF

Modification of DEF Time Delay step from 100 ms to 2ms

SBEF with 4 stages (IN>1 to IN>4)

Extraction of the internal TRACE (windows tool not yet available)

P44x Phase 2 Development

Version C1.0 - available from April 2004Version C2.2 - available from Sept 2004


Power Swing Logic modified:

Detection is now realised by using phase-to-phase loops to ensure a better phase-to-ground resistance coverage.

Additional Delta Fault Detector used during Power Swing condition to unblock distance element by 3 phase fault independently of the faulty current value.

Additional Delta Fault Selector used to determinate the faulty phase if a fault occurs during power fault (previous firmware force a 3 phase fault selection).

Relay is able to differentiate an out-of-step condition from a stable power swing (sign of R). Out-of-step tripping can be realised by PSL.

A trip can be issued using PSL when a certain number of Out-of-step or/and stable power swing conditions has been reached

Zone Decision is filtered by Power Swing Logic during TOR condition to avoid an instantaneous trip if reclosing on power swing condition and if any of 6 loops within the distance characteristic.

P44x Phase 2 DevelopmentVersion C1.0 - available from April 2004 Version C2.2 - available from Sept 2004


Recent RTDS testing have been conducted to verify the CT requirements with the new version C1.0: CT Knee Point Voltage for Phase Fault Distance Protection

Vk ≥ KRPA x IF Z1 x (1+ X/R) . (RCT + RL)

Where:

Vk = Required CT knee point voltage (volts),

KRPA = Fixed dimensioning factor = always 0.6

IF Z1 = Max. secondary phase fault current at Zone 1 reach point (A),

X/R = Primary system reactance / resistance ratio,

RCT = CT secondary winding resistance (Ω),

RL = Single lead resistance from CT to relay (Ω).

CT Requirements


Recent RTDS testing have been conducted to verify theCT requirements with the new version C1.0: CT Knee Point Voltage for Earth Fault Distance Protection

Vk ≥ KRPA x IFe Z1 x (1+ Xe/Re) . (RCT + 2RL)

Where:

KRPA = Fixed dimensioning factor = always 0.6

IFe Z1 = Max. secondary earth fault current at Zone 1 reach point (A),

Xe/Re = Primary system reactance / resistance ratio for earth loop.

CT Requirements


Model 30H/30G/30J (Cortec modified)

Thermal overload function (as P540) - dual time constant

Measurement 3: Thermal status

Alarm : 50% - 100%

Log curves

Dual alarm between copper & oil

UCA2 - DNP3/Kbus/ModBus/103… 61850-8-1 soon

Input synchro included in the DDB

Opto configuration - with/without filtering - included or not in the events

DEF settings: IN Rev Factor (0,6 - 1)

30J: Dual Optos for china’s market

Version C1.0 - available from April 2004 Version C2.2 - available from Sept 2004

P44x Phase 2 DevelopmentVersion C2.x


Analogue toDigital Conversion and Filtering

Analogue todigital

conversion

24 samplesper cycle

Lowpassfilter

1 Sampledelay

FIRcurrent

derivative

i

uu

i

di/dt

24 Samples per cycle (>B1.x)

I

U

Antialiasing

1 Sampledelay

Lowpassfilter

Anti aliasing

48 Samples per cycle (>B1.x)

F sampling for Dist.Rec. is 24 samples/cycle since version B1.X

24 Samples per cycle (AX) 12 Samples per cycle (AX)


Analog to Digital Conversion and Filtering((AX) 24 samples - (>B1.x) 48 Samples )

Analogue & Numerical Filters

C.A.N

Analog FiltersAnti-aliasing

AnalogChannels

Digital FiltersFc << 300Hz

1 sample / 2

T.F.D

Harmonic 1 and 2 (50 and 100Hz)


Analog to Digital Conversion and Filtering

Low Pass Filter: frequency cut out 150 Hz, 250 Hz, 350 Hz, 500 Hz & 600 Hz

0 1 0 0 2 0 0 3 0 0 4 0 0 5 0 0 6 0 00

0 .2

0 .4

0 .6

0 .8

1

1 .2

1 .4

F r é q u e n c e

Am

plitu

de

F i l t r e p a s s e - b a s


Analog to Digital Conversion and Filtering((AX) 12 samples - (>B1.x) 24 Samples )

Delay

Low Pass

Derivative Filter

High Pass Filter Posit&Negat seq. Filter

Numerical Filters



High Pass Filter: frequency cut out 0 Hz, 300 Hz & 462 Hz.

0 1 0 0 2 0 0 3 0 0 4 0 0 5 0 0 6 0 00

0 .5

1

1 .5

2

2 .5

F r é q u e n c e

Am

plitu

de

F i l t r e p a s s e - h a u t



Derivated Filter: frequency cut out 0 Hz, 300 Hz & 462 Hz.

0 1 0 0 2 0 0 3 0 0 4 0 0 5 0 0 6 0 00

2 0 0

4 0 0

6 0 0

8 0 0

1 0 0 0

1 2 0 0

F r é q u e n c e

Am

plitu

de

F i t r e d é r i v a te u r


Hardware Overview MiCOM P440


MiCOM Hardware - Example of Front Housing View 80TE (1)

LCD - 3 lines

ProgrammableLEDs

Fixed LEDs

Bottom Flap Masking RS232 COM port and Battery


Available Informations of Front Housing

MiCOM Hardware - Example of Front Housing View 80TE (2)Serial N° and

CORTEC Code identifying the

product

NavigationArrow

Battery:Disturbance Event

Maintenance MessageSK1: DB 9 points- Settings / PSL

- Extraction (evt/Pert)- Reset Leds

SK2: DB 25 points- Text editor

- Flash Version

Consultation/Effacement Compte Rendus

2 Hot Keys


MiCOM HardwareTeminal Blocks Rear View

Rear View of the Housing 40-60-80TE

AnalogicalModule

Inputs/OutputsModule

EthernetModule

ModuleIRIGB


Protection Features MiCOM P440


P440 Distance & Other Protection Functions

Thermal Overload

Under / OverVoltage

Switch on toFault & Tripon Reclose

Power SwingBlocking

BrokenConductorDetection

NegativeDirectional Sequence

Overcurrent

DistanceProtection

Directional / non Directional

Overcurrent

Channel Aided Distance / DEF

Directional / non Directional

Earth FaultBreakerFailure

Out Of StepLogic


Distance Protection MiCOM P440


P440 Distance Protection

Parallel Line

Distance ProtectionAlgorithms

Trip on RecloseSwitch on to fault

Zone 1 ExtensionLoss of Load Channel

Aided Trip

Weak Infeed and Echo Mode

PAP


Distance Protection AlgorithmsProper Fault Clearance

Fault Detection

Secure Phase Selection

Evolving Faults

Power Swings

Directional Security

Flexible Distance Zones

Fast Fault Clearance

Non-Pilot & Pilot Logic (Distance Aided Schemes)

HydroQuebec-Canada

TNB-Malaisie

EPRI-Chine

ONE-Maroc

Terna-Italie

Enel-ItaliePowerGrid-Indes

EETC-Egypte

Lapem-Mexique

-Brézil … Qualified in many utilities


Distance Protection AlgorithmsFull Scheme Distance Protection

Five Quadrilateral Zones (Tilt in option)

Z4

R

X

Directional Linefixed at: - 30°(Deltas & Classical)

Z3

Z1

Z2

Additional Fwd. / Rev.ProgrammableZone pZp


Distance Protection AlgorithmsDistance Scheme

Distance operation settable (21P, 21G or both)

Zone operation settable (Z1X, Z2, Zp, Z3 & Z4)

Zp Direction programmable

Zone overlapping or zone selection

Single or three pole tripping (P442 & P444)


Impedance Measurement AlgorithmsR and X Measurement

Compute R and X for 6 impedance loops (ZAN, ZBN, ZCN, ZAB, ZBC, ZCA)

Line characteristics: R = line resistance (Ω/km) X = line reactance (Ω/km)

Fault characteristics: D = calculated position of the fault (km) I = fault current on the faulty phase(s) as

measured by the relay (A) RF= apparent fault resistance (Ω) V = (R + jX) x I = linear voltage drop on

the line (V/km) U = voltage measured by the relay (V) J = fault current through the fault

resistance(A) Ir = residual current

U =D x V + RFault x J

=D x (R + jX) x I + RFault x J

ZSource ZLine

D

U

I

J RFault


Setting Applied for GroundFault Detection

Fault

IAZS

VAVS R1 Gnd

Z1 Gnd

Line Ground Reach

Ground Loop Model

Ra

Xa

Z1R1gnd/1+kZN

Z1 gnd

A-N Zone 1 shown:

IA

Line Residual Reach

kZn x Z1 GndIN



Phase-to-ground loop impedance:

VαN = ZL x D x (Iα + kO x 3I0) + RFault x J with α = (A, B or C)

And J = 3I0 during the first 2 cycles and then J = Iα

V1

V2

V3

Zs

Zs

i3

i1

ZL

Zs i2

ZL

ZL

V3N V2N V1N kS ZS kL ZLRFault

Location of Relay

Z Fault

Z L

R Fault/(1 + K0)

Z0 - Zd

3 x Zd

k0 =

X Ω/phase

R Ω/phase



For phase-to-earth loop impedance: VAN = ZL x D x (IA + kO x 3I0) + RFault x J

VBN = ZL x D x (IB + kO x 3I0) + RFault x J

VCN = ZL x D x (IC + kO x 3I0) + RFault x J

x 4 kO residual compensation factors = 12 loops

The derived faulted phase current is used for measurement after the first 2 cycles for fault in zone 2, 3, P and 4 because the zero sequence current 3I0 can be erroneous due to a single-phase CB opening in the network.



For phase-to-earth loop impedance:For phase-to-earth loop impedance:1.1.1. CARACTERISTIQUE MONO AVEC ZONE P AVAL

Zone4

Zone1

Zone3

ZoneP

Zone2

Zp

Z3

Z2

Z1

K03

K0p

K02

K01

R3G

RpG

R2G

R1G

X

R

Z1, Z2, Z3, Zp, Z4 : limites des zones 1, 2, 3, p, 4R1G, R2G, R3G, RpG : portée en résistance des zones 1, 2, 3, p, 4 pour les

défauts monophasés.K01, K02, K03, K0p : coefficient de compensation résiduelle des zones 1,

2, 3, pLes zones 1, 2, 3 et P peuvent avoir des portées en résistances et des coefficients de compensationrésiduelle différents. Les zones 3 et 4 ont les mêmes portées en résistances et coefficients decompensation résiduelle. Les coefficients de compensation résiduelle dépendent de lacaractéristique de la ligne sur chaque zone.

angle de ligne : ϑ pg ArgZ Zx

=+

23

1 0* où Zx0 est l’impédance homopolaire pour la zone x et

Z1 est l’impédance directe.


Setting Applied for PhaseFault Detection

Fault

IA - IBZS

VABVS R1 Ph / 2

Z1 Ph

Line Phase Reach

Positive Sequence Model

Rab

Xab

Z1R1ph/2

Z1 ph

A-B Zone 1 shown:



Phase-to-phase loop impedance:

Vαβ = ZL x D x Iαβ + RFault /2 x J with αβ = (AB, BC or CA) and with J = Iαβ

RFault

V1 V2 V3

Zs

Zs

Zs

i3

i2

i1

ZL

ZL

ZL

V3N V2N V1N

Location of Relay

Z Fault

Z L

R Fault/2X Ω/phase

R Ω/phase



For phase-to-phase loop impedance: VAB = ZL x D x IAB + RFault /2 x J

VBC = ZL x D x IBC + RFault /2 x J

VCA = ZL x D x ICA + RFault /2 x J

= 3 loops

The protection has 15 measurement loops.

The measurements are true reactance measurements, i.e. insensitive to effects of load current and fault resistance.

All 15 loops will be computed every 0,69 ms at 60 Hz. (24 samples per cycle)



For phase to phase loop impedance:For phase to phase loop impedance:

1.1.1. CARACTERISTIQUE BIPHASEE AVEC ZONE P AVAL

Z3

Zp

Z2

Z1

R3Ph

RpPh

R2Ph

R1Ph

Zone4

Zone3

Zone2

ZoneP

Zone1

R

X

Z1, Z2, Z3, Zp, Z4 : limites des zones 1, 2, 3, p, 4R1Ph, R2Ph, R3Ph, RpPh : portée en résistance des zones 1, 2, 3, p pour les

défauts biphasés.Dans le cas d’une caractéristique biphasée, toutes les zones ont le même angle de ligne :l’argument de Z1 (impédance directe).



Gauss-Seidel (Last mean square iterative mathematics method)

Σ U x J - D N-1 x Σ V x J

Σ (J)²R Défaut N

=

Fault resistance R Fault :

Σ U x V - R fault N-1 x Σ V x J

Σ (V)²D N =

Fault distance D :


Impedance Measurement Algorithms R and X Measurement - Gauss-SeidelGauss-Seidel

Vα 1 = ZL . D . Iα 1 + RF. IF1 + ε 1

Vα i = ZL . D . Iα i + RF. IFi + ε i

Vα n = ZL . D . Iα n + RF. IFn + ε n

Σ (ε i)2 = Σ (Vα i - ZL . D . Iα i - RF. IFi)2 (Last mean square method)

∂ Σ (ε i)2 /∂ (ZL.D) = 0 et ∂ Σ (ε i)2 /∂ RF = 0

∂ Σ (ε i)2 /∂ (ZL.D) =∂ Σ (Vα i-ZL.D.Iα i-RF. IFi)2 /∂ (ZL.D) - Derivate calculation -=Σ [2.(Vα i-ZL.D.Iα i-RF. IFi).(-Iα i)=0]

∂ Σ (ε i)2 /∂ RF =∂ Σ (Vα i-ZL.D.Iα i-RF. IFi)2/∂ RF= Σ [2.(Vα i-ZL.D.Iα i-RF. IFi).(-IFi) =0]

Σ (Vα i . Iα i) = ZL.D. Σ (Iα i)2 + RF. Σ (Iα i . IFi)

Σ (Vα i . IFi) = ZL.D. Σ (Iα i . IFi) + RF. Σ (IFi)2

ZL.D n = [Σ (Vα i . Iα i) – RF n-1. Σ (Iα i . IFi)] / Σ (Iα i)2

RF n =[ Σ (Vα i . IFi) - ZL.D n-1. Σ (Iα i . IFi) ] / Σ (IFi)2

The above system is solved by iterative method:


Distance Protection Algorithms

Dual distance protection algorithms

The operation of MiCOM P440 is based on the combined use of two types of algorithms for a fault detection:

Algorithm 1: Fault detection using superimposed

quantities: Delta algorithm (Startup: ∆I or ∆V )

Algorithm 2: Fault detection using resistance/reactance:

Conventional algorithm (Startup: minZ )


Delta algorithms

The patented algorithm has been proven with 15 years of service at all voltage levels.

The P440 relay has ultimate reliability of phase selection and directional decision far superior to standard distance techniques.

The delta algorithms are based on transient components.

Distance Protection AlgorithmsDelta Algorithms


Delta algorithm using superimposed values

Fault confirmation

Forward fault detection

Phase selection

Convergence of calculated R and X within quadrilateral zone

Trip time with new coprocessor board: Fastest Trip Time 0.85 cycle

Typical 1.1 cycle

T = 1/2 cycle

Distance Protection AlgorithmsDelta Algorithms/Principle


Faulted Phase Selection

Compares pre-faulted system

Acts as a fault detector and faulted phase detector

Can quickly recognize evolving faults and power swings

Provides secure phase selection for complex fault conditions

Sensitive to any fault type

All P44x Use Superimposed Current

Works Automatically - with no settings needed


↑ ∆Y(t) = Y(t) - Yp(t)

Y(t) currents or voltages

Sampled waveform “y”

Predicted and Superimposed Values


Y(t-2T) = Sample two cycles prior to t

Y(t-T) = Sample one cycle prior to t

Yp(t) = Predicted value of Y at time t = 2.Y(t-T) - Y(t-2T)

↑


IApf

Unfaulted line (predicted) VApf

F

VFpf

IA

Faulted line VA

F

Rfault

∆VA=VA-VApf

∆IA=IA-IApf

Superimposed Deltavalues: ∆VA

∆IA

-VFpf

Rfault

Calculation of Superimposed Values



















A transition is detected if: ∆I > 20% In OR ∆V >10% Vn

Then three tasks are starting in parallel: Fault confirmation: ∆I AND ∆V

Faulty phase selection

Fault direction determination

(classical directionnal computed in parallel)


(3 consecutive samples)



Confirmation

Phase selection

Direction

Start ∆


Phase Selection

Current derivative values are used to eliminate the effect of dc transients

Derivative currents are squared prior to magnitude comparison Sx = Σ(∆ I'x)² for the six loops

Phase-to-phase values are sorted into ascending order and compared

Example SAB < SBC < SCA

- If SAB << SBC , the fault has had minimal effect on the loop AB. The fault is single-phase (C).

Distance Protection AlgorithmsDelta Algorithms/Phase Selection


Phase selection If no single phase fault is detected, phase values are

sorted into ascending order and compared Example SA < SB < SC

- Fault affects at least the ring main (B,C)

- If SA << SB , the fault is phase-to-phase (B,C)

- If SAB ≈ SBC ≈ SBC and SA ≈ SB ≈ SC the fault is three-phase (A,B,C)

Distance Protection AlgorithmsDelta Algorithms/Phase Selection


Distance Protection AlgorithmsDelta Algorithms/Fault Direction

Fault direction is determined according to the sign of transient energy characterising the fault. Transition energy is the energy created by the fault and is given by:

The sign of the energy is used for detection of fault direction as follows:

- S = ∫ U x I x dt


For forward faults ∆I is in reverse direction to the relay’s CT orientation The power supplied through the relay is:

P = - ∆I². Zs

The energy is: S = - ∫ ∆I². Zs. dt, which is always negative


Forward faultV I

Zone 1


For a reverse fault ∆V = ∆I. Zs is positive while ∆I is in same direction as the relay’s CT orientation, hence:

The power supplied through the relay is: P = - ∆I². Zs

The energy is:

(S = + ∫ ∆ I ². Zs. dt,) always positive for a reverse fault.


Reverse faultV I

Zone 1


Delta Directional Comparison:Forward Fault Decision

Forward fault

V I

Forward direction

∆V

- ∆V∆I∠-Zs

Delta I lags inverted Delta VDelta I lags -∆V according to the

characteristic angle of the source impedance behind the relay

60° degrees for lines (by default), 0 degrees used for series compensated line

applications (Series Cmp. Line = “Enabled” in P442).

P442 P443



The fault direction is determined by the sign of the transient energy S calculated by phase:

SA=Σ ∆UA x ∆IA , SB=Σ ∆UB x ∆IB , SC=Σ ∆UC x ∆IC

If fault in AN then S = SA If fault in BN then S = SB If fault in CN then S = SC

If fault in AB and if SA or SB<0 If fault in BC and if SB or SC<0 If fault in CA and if SC or SA<0 If fault in ABC and if SA or SB or SC< 0

then Forward Fault

otherwise Reverse Fault

If S<0 then Forward Fault

If S>0 then Reverse Fault




Validity conditions: Power system frequency is being measured and tracked

Line is not open

All voltages are between 70% and 130% of the nominal value

The residual current is less than 10% of the nominal value + 3.3% of the maximum current flowing on the line

There is no power swing

2 cycles of healthy pre-fault data are stored



Conventional algorithms use the 15 measuring loops of impedance (AN, BN,CN, AB, BC, CA)

Under impedance Z< starting

Start when at least 1 of the 15 measuring loops converges within the start-up characteristic (Z3 and Z4)

Distance Protection AlgorithmsConventional Algorithms


Phase selection

Current phase selection Amplitudes I’A, I’B and I’C derived from the three phase currents IA, IB and

IC are measured and compared to each other and to the two thresholds S1 (= 3 x IN) and S2 (= 5 x IN)

Example I’A < I’B < I’C

- If I’C > S2, I’B > S1 and I’A > S1, the fault is three-phase

- If I’C > S2, I’B > S1 and I’A < S1, the fault is two-phase (BC)

- If I’C > S2, I’B < S1, the fault is single-phase (CN)

- If I’C < S2, the current phase selection cannot be used.



Impedance phase selection

Impedance phase selection is obtained by checking the convergence of the various measuring loops within the start-up characteristic

T = presence of zero-sequence voltage or current

ZAN = Convergence within the characteristic of the loop AN

ZBN = Convergence within the characteristic of the loop BN

ZCN = Convergence within the characteristic of the loop CN

ZAB = Convergence within the characteristic of the loop AB

ZBC = Convergence within the characteristic of the loop BC

ZCA = Convergence within the characteristic of the loop CA



Impedance phase selection In addition, the following are also defined:

RAN = ZAN . /ZBC with /ZBC = no convergence within the characteristic of the loop BC

RBN = ZBN . /ZCA with /ZCA = no convergence within the characteristic of the loop CA

RCN = ZCN . /ZAB with /ZAB = no convergence within the characteristic of the loop AB

RAB = ZAB . /ZC with /ZC = no convergence within the characteristic of the loop CN

RBC = ZBC . /ZA with /ZA = no convergence within the characteristic of the loop AN

RCA = ZCA . /ZB with /ZB = no convergence within the characteristic of the loop BN



Impedance phase selection The different phase selection are:

SAN = T . RA . /RB . /RC single phase A to ground fault SBN = T . RB . /RA . /RC single phase B to ground fault SCN = T . RC . /RA . /RB single phase C to ground fault SAN = T . RA . /RB . /RC single phase A to ground fault SAB = T . RAB . ZA . ZB phase-to-phase AB to ground fault SBC = T . RBC . ZB . ZC phase-to-phase BC to ground fault SCA = T . RCA . ZC . ZA phase-to-phase CA to ground fault SAB = /T . RAB . /RBC . /RCA phase-to-phase AB fault SBC = /T . RBC . /RCA . /RAB phase-to-phase BC fault SCA = /T . RCA . /RAB . /RBC phase-to-phase CA fault SABC = ZA . ZB . ZC . ZAB . ZBC . ZCA 3 phase fault




Directional decision Phase shift between the pre-fault voltage and the fault

current

For single-phase loops: Phase shift between the stored voltage and the current

derivative I’α + kO x 3I’0 with α = (A, B or C)

For two-phase loops: Phase shift between the stored voltage and the

derivative of the current I’αβ with αβ = (AB, BC or CA)

Directional angle is fixed between -30° and +150°


Theoretical Distance Relay Operating Requirements

X

Fault + arc impedanceregion

ZLine1) Trip for internal fault2) Stable for all loading

R

Z load

Load impedance


Effects of Infeed and Outfeed:Apparent Arc Resistance Change

X

R

Z load

Arc impedance withRemote end infeed

ZLine

Load impedanceregion

load export

load import


Z3Z3

Z1Z1

Z2Z2

Z4Z4

R

X

Directional Line

ZpZp

Using P442 family relaysSetting of Right-Hand resistive reach

Five Quadrilateral Zones

This line serves as the load

blinder, and the resistive

coverage, in one setting


Surveillance des 3 boucles AB, BN,AN

Position des boucles dans différentes zones (AN=Z1/AB=Z2/BN en dehors)

Solution appliquée: Afin d ’éviter une sél.de phase mono Z1, la caratéristique est étendue (X3étendue=2R3)

Protection de DistanceAlgorithmes Classiques - Sélection de phase à minZ sur défaut Bi-Terre (exemple:ABN)

ANAB

R DéfautV

A

VB

VC

Zs

Zs

Zs

iC

iB

iA

Zd

Zd

Zd

VB

N

VA

N

BNBN

BN


Quadrilateral Characteristic Advantages

Zone reach setting (Z) and Resistive reach (R) setting are independentAllows resistive reach to be set exactly according to the

fault arc coverage required

No need to rely on characteristic expansion - you get what you set!

Resistive reach setting acts as the load blinderMakes characteristic applicable to lines of all lengths,

without risking load encroachment trips

Characteristic simplicity - easy to test and commissionResistive reach is constant throughout the length of the

zone


R

01234..

All zone timers started at the instant of fault detection Rn-1 < Ri and Rn < Ri and |Rn-1 - Rn| < 10% x Ri Xn-1 < Xi and Xn < Xi and |Xn-1 - Xn| < k% x Xi

With k= 5% for zone 1 and 10% for other zones With i=1,1X,2,p,3 and 4

Trip Decision on X/R Convergence in Zone

Directional Line

Distance Protection AlgorithmsDelta/Conventional Algorithms


R

0123

4..

<10% change in between R & X iterations gives convergence n=n+1

<5% change in between R & X iterations gives convergence n=n+2

n= 6 zone decisionfor Z1, Z1X, Z2 and Zp

n= 2 zone decisionfor Z3 and Z4

Trip Decision on X/R Convergence in Zone

Distance Protection AlgorithmsDelta/Conventional Algorithms




Delta Algorithms: Start ∆V or ∆I Delta Algorithms:

AC Phase Selection

Delta Algorithms: Sending Direction

Zone Decision:Zone 1

Classic Algorithms:ZAC Convergence

Trip

Distance Protection AlgorithmsDelta Algorithms (Example in Version A4.x)


Distance Protection AlgorithmsAlgorithms Chaining

Switch-on-to-fault

Acquisition and filtering of samples

Line open

Impedance measurements on all 15 loops

Network healthy

Detection oftransition

Convergence in characteristic

of all 6 loops

Phase selection Direction

Fault confirmation

Phase selection Direction

Tripping logicDecision to trip using delta algorithms during 40 ms

Decision to trip using classic algorithms

Y

N

N

N

Y

Y

Y


Modification of the distance algorithm chaining Distance Start:

(∆U OR ∆I) with ∆U > 10% Vn and ∆I 20% > InOR

Z< (classical)

Directional Decision: The sign of transient energy (Σ ∆U x ∆I) is used if (∆V AND ∆I) is

verified,ELSE

Direction decision of the classical algorithms is used (angle between pre-fault voltage and faulty current)

Phase Selection: ∆I phase selector is used if ∆I verified (S = Σ ∆’I)OR

Classical Current Phase Selector is usedELSE

Classical Impedance Phase Selector is used

P44x Phase 2 DevelopmentVersion B1.2 - available from June 2003


Distance Protection - Algorithms Chaining detailed

DIRECTIONAL

DISTANCE PHASE SELECTION

&

IMPEDANCEMONITORINGGAUSS-SIDEL

15 Loops

PREDICTIVES VALUES AND DELTA

Gp(t) = 2G(t-T)-G(t-2T)

FaultDetection

IMPEDANCECALCULATION

FOR MEASUREMENTS

Start All Timers

Distance Convergency

ZONE CONVERGENCY

CRITERIA

CLASS. ALGORITH.

FAST ALGORITHM12 mono loops using

K0*Ir3 biphase quantities

loops

CLASS. ALGORITHM15 loops using

phase/ biphase quantities

T1(DDB 261)T2 (DDB 262)

T3 (DDB 263)TZP (DDB265)

T4 (DDB 264)

Tp (Transmission time)

DIST FWD NO FILT (DDB 343)

DIST REV NO FILT (DDB344)

Z1NOT FILTERED (DD349)

Z1X

Z2

ZP

Z3

Z4

DIST START A* (DDB 249)

DIST START B* (DDB 250)

DIST START C* (DDB 251)

DIST START N (DDB 354)

DIST REV GUARD (DDB 270)

VAVBVC

IAIBIC

IV ∆∆ ,

Delta detected

MEMORY VOLTAGE

RX ∆∆ ,

FAST ALGORITHM

DIST CONVERGENCY (DDB 345)

&

&

DIST FWD

DIST REV

* As to be combinated respectively with Weak Infeed start A, B, C

Ω

CLASS. ALGORITHMI Phase selection Phase selectionΩ

FAST ALGORITHM

PulseTrevG

...)( 2∑ ∆= IadSA

...)*( +∆∆= IaVaS

Phase(Vmemory, I+ K0Ir)


All zones have individually adjustable (Z, RPh, RG, kZ0 Residual Compensation amplitude and angle)

This is an advantage for hybrid lines (overhead to cable) and transformer protection as P440 more accurately models the line

Quadrilateral distance zones set to give good fault arc resistive coverage whilst avoiding load

Four alternative setting groups available to suit switched feeding arrangements

Distance Protection AlgorithmsAdaptable Distance Zones


Distance Protection AlgorithmsAdaptable Distance Zones

Hybrid Line: Cable / Overhead line

Z1A= 1,2 ZC

Gas IsolatedSubstation Overhead

Substation

Z1B= 1,2 ZL

Z0C < θC Z0L < θL

Exact adaptation of Z1 setting to Z0 angle of the

protected section

θC

θCK0 = (Z0 – Zd)/3Zd = K0r + jK0x

K0r = (Rd*(R0-Rd)+Xd*(X0-Xd))/(3*(Rd²+Xd²))

K0x = (Rd*(X0-Xd)-Xd*(R0-Rd))/(3*(Rd²+Xd²))


Résistance de couverture par zone utilisée dans le cas d’une protection de ligne courte: R/X = 10

Limites de caractéristique en RBi et Rmono (possibilité de

recouvrir la zone de charge

Protection de DistanceCaractéristique en Forme de Parallélogramme

X

R Zone de Charge

Z3

RMonoRbi

Limite Mise en Routedes boucles monos

Boucles Bi

Limite DétectionBande de Pompage


Channel Aided Distance MiCOM P440


Direct Intertrip (using PSL)

Blocking (BOP)

Permissive Underreach(PUP)

Permissive Overreach (POP)

POP with weak infeed logic

On Channel Fail: LOL or Z1X

POP with weak infeed logic, and weak infeed trip

Unblocking on Loss of Guard in FSK Power Line Carrier Schemes

Unblocking on Loss of Carrier in Non-PLC Schemes

P440 Pilot Logic Schemes (21P, 21G)

Channel Aided Distance Schemes



Distance Protection: Basic Scheme

T3A

PA PB

Z1A=0.8 ZLZ2A=1.2 ZLZL

Z2B=1.2 ZL Z1B=0.8 ZLZL

T1A

T2A

T1B

T2B

T3B Sequence 1

PA PB

CBCBCB CB


Distance Protection: Fault in Z1

ZL

T1A

T2A

T3A

Sequence 2

T1B

T2B

T3B

CB

PA PB

Z1A=0.8 ZL Z2A=1.2 ZL


CB CBCB

T1BT1A



Distance Protection: Internal fault in Z2

Z1A=0.8 ZLZ2A=1.2 ZLZL


T1A

T2A

T3A

Sequence 3

T1B

T2B

T3B

PA PB

CBCBCB CB

T1BT2A

(delayed)



Distance Protection: External fault in Z2 (Beyond relay C)

T1A

T2A

T3A

Z1A=0.8 ZL Z2A=1.2 ZL

ZL


Sequence 4

PC

T1C

T2C

T1B

T2B

T3B

PA PB

CBCBCB CB

T1C



Channel Aided Permissive Underreach scheme (PUP)

T1A

T2A

T3A

PA PB

Z1A=0.8 ZL Z2A=1.2 ZLZL


Send = Z1B

T1B

T2B

T3B

PA PB

CBCBCB CB

T1B>T1A

PC

Aided tripping



Channel Aided Permissive Overreach Zone1 (POP Z1)

PA PB

Z1A=1,2 ZLZL

Z1B=1,2 ZL ZL

T1A

T2A

T1B

T2B

Send = Z1A

Send = Z1B

PCPA PB

CBCBCB CB

T1A T1B



Channel Aided Permissive Overreach Zone 2 (POP Z2)

Z2A=1.2 ZLZL

Z2B=1.2 ZL ZL

T2A

T1A

T1B

T2B

Send = Z2A

Send = Z2B

PA PB

CBCBCB CB

T1BT1A



Channel Aided Blocking Overreach Zone 2 (BOP Z2)

Sequence 1: External Fault in Z2A



T1A

T2A

T3A

Send Z4B(Blocking signal)

TZ4B

T1B

T2B

T3B

T1C

T2C

PA PB

CBCBCB CB

Forward Z2 Reverse B

T1C



Channel Aided Blocking Overreach Zone 2(BOP Z2)

Sequence 2: Internal fault in Z2A



T1A

T2A

T3A

T1B

T2B

T3B

PA PB

CBCBCB CB

Tp>T1A

Blocking signal

Forward Z2

T1B



Weak Infeed Mode or PAP(RTE application)

MiCOM P440


Weak Infeed Mode

EA EB

PA PB

Weak source

I # 0

VAN = ZL x D x (IA + kO x IR) + RFault x (I’R + IR) with I’R > IR , ZL x D and RFault high values

Single or three pole tripping Phase selection using U< Check of CB position or Line open condition

I R I’ R


Protection of T line (RTE application)

Implantation of T line (passive antenna) in conformity with RTE specifications Single and Three-phase trip Phase selection by voltmetric balances


Functional decomposition: Measurement and analysis functions

Measurement function (starting from analogical sizes)

Analysis function (supplying commissionings)

A treatment function:Channel-aided trip function

time delayed trip function

Presence of residual current function

Composition (1/2)



Inputs sizes: From the process (HT/THT network)

Three phase voltages VA, Vb, Vc, Ir Residual curent, Channel-aided trip reception, interlocks.

From the Configuration: Commissioning/out of service function, Ir, Thresholds commissioning voltage.

Composition (2/2)



=> Gives a phase selection information

=> Lockout with a distance start

Note: Residual current pickup is maintained 600ms after dropOff.

Measurement Function

Start Prot. Distance

AnalysisFunction

Measurement and Analysis Function Scheme

Single

Multiple



=>Gives a commissioning information (phase or residual current): Mr A, Mr B, Mr C

Single or three-phase selection,

Ir pickup,

Commissioning by Ir

Note: Commissioning residual current is only active if no selection phase is validate and measurement of a residual current.

Analysis Function



Analysis LogicStart Prot. Distance

Single

Multiple



Channel-aided trip:(IHM commissioning/out of service) Goal:

Allow a quick elimination of faults from TAC reception

Action on the process:Single or Three-phase trip (according to selection phase) with logic information reception.«Channel-aided trip» coming from the other limit.Auto-Recloser launching

Note : TAC reception is memorised 650 ms

Treatment (1/6)



Logic channel-aided trip:

Treatment (2/6)

Teledec ON

cmd Teledec

Teledec A

Teledec B

Teledec CPoly

Mr C

Poly

Mr B

Poly

Mr A

MrIrAutoris_Ir

Teledec Ir

Channel-aided trip

Cmd Channel-aided trip

Multiple

Multiple

Multiple

Lr Authorization

A Channel-aided trip

B Channel-aided trip

C Channel-aided trip

lr Channel-aided trip



Time delayed trip: (IHM commissioning/out of service) Goal:

Allow faults elimination in a time delayed way when channel-aided trip is not possible

Action on the process:Time delayed trip (settable time delay)Auto-Recloser launching

Treatment (3/6)



Specific parameters: Time delayed trip (Tm & Tt)

Single trip authorization (P1)

DEC possible confirmation of single on lr presence (P2)

Inhibition of three-phase trip (except selection phase informations) (P3)

Time delayed trip blocking conditions: PAP External active time delayed interlock (TS)

Logic input « no breakdown transmission » active (TS)

Fuse failure line pickup (internal or external), except if lr presence

Treatment (4/6)



Logic function « Time delayed trip »:

Treatment (5/6)

A Time delayed trip

B Time delayed trip

C Time delayed trip

Single

Multiple

Time delayed trip under-function

PAP time-delay TS interlock

TS ’s transmission breakdown abscence

Detection line fusion fuse

EN/HS Time delayed trip



Residual current presence: Goal:

Signal presence of a residual current beyond a 10 seconds fixed duration.

Action of the process:Indication (TC)

Treatment (6/6)



Note: The auto-recloser start on a channel-aided trip or a time delayed trip.

Teledec C

DecTemp CDec PAP C

Teledec B

DecTemp BDec PAP B

Teledec A

DecTemp ADec PAP A

Discordance de pÙle

Verrouille ARS0

50DJ fermÈ

PAP and Auto-recloser (1/4)

A Channel-aided trip

A Time delayed trip

B Channel-aided trip

B Time delayed trip

C Time delayed trip

C Channel-aided trip

Dj Closed

Out of Pole

PAP A Trip

PAP B Trip

PAP C Trip

ARS Interlock



Specific logic inputs (5): Channel-aided trip reception (1), => Channel-aided trip

External interlock => Only interlock timedelayed trip

No fault channel-aided trip link (2) => Usually always at 1

Breaker closed (3)

Out of pole (3)

PAP and Auto-recloser: associated inputs/outputs (2/4)



Note (1): independant inputs or not the one of main protection (no confirmation)

Note (2) : coming from the process or from the other limit (no confirmation)

Note (3) : not used inputs in V1E version

PAP and auto-recloser: associated inputs/outputs (3/4)

Trip outputs (specific): DEC PAP A, DEC PAP B, DEC PAP C

(DEC Px A, B, C more informations)



Specific output indications: Selector operation (PAP starting)

Supply on residual current (PAP)

Trip lr supply on residual current

PAP A, B, C Trip

Non specific output indications: Phase selection A, B, C, Three or single fault

Auto-recloser interlock,

Fault equipment.

PAP and Auto-recloser: associated inputs/outputs (4/4)



Delayed one pole Trip

Trip allowed

Micom S1 settings = WinEPAC Page (p1/3)



Page P44x IHM MiCOM S1-settings (p2/3)



Page P44x IHM MiCOM S1- PSL settings (In/out) - (p3/3)



Extended ZoneMiCOM P440


DJ1

Zone 1 Extended

A B

DJ2

A B

DJ1 DJ2

Zone 1

Zone 1 Extended


Acceleration Phase by Opening Opposite limit

Operate for three- phase trip Operate only for single, phase-to-phase or phase-to-phase-to-ground faults Require a preliminary load current

Principle: The fault located beyond 80% of the line is instantaneously tripping by the remote end distance relay (fault detected in zone 1) After 3 phase opening of the remote CB, there is no more any load current on the healthy phase(s) Presence of faulty current + above condition= Loss of load condition - zone 2 tripping accelarated


Loss of load Logic

T1

T2Z1 Z2

CB

CB

CB

CB

CB

CB


Loss of load Logic

Z2

I=0

I=0

I≠0

T1

CB

CB

CB

CB

CB

CB

DJA DJB

Z2 tripping accelarated

after remote CB opening


Switch on to Fault & Trip on Reclose MiCOM P440


X

X

X

Switch on to Fault (SOTF) (1)

Fast tripping for faults on line energisation, even where line VTs provide no prefault voltage memory

In service for 500ms following CB Closure (Input)


Fast tripping using: I>3 overcurrent protection

or

Level detector

or

Distance protection (zone operation settable Z1, Z2, Zp, Z3 or Z< starting) with supervision by Inrush Current Detection

Fastest operating time: 10 ms (I>3) 20 ms (Z<)

Switch on to Fault (SOTF) (2)


As SOTF: Except if:

Zone 1 extension,

or Channel Aided Distance (directional comparison)

Differentiation between 3 pole TOR and SOTF can made using a settable line open time delay.

Trip On Reclose (TOR) (3)


Fault on Reclose (SOTF/TOR logic) (4)

S1 Settings:

SOTF Settings:

TOR Settings:


TOR-SOTF Logic Scheme (starting)



TOR-SOTF Logic scheme (Trip)



Parallel Lines MiCOM P440


Z4 Z2

Z1 Z2

Z2 Z4

Z2

Parallel LinesCurrent Reversal Guard


Parallel LineDifferential Algo./Fault location

Differential Algorithms for phase selection:

Extra CT input for mutual compensation (only used for fault location)

AN fault forward

BN fault reverseZ2 ABN fault

AN

BN

Z1 AN fault

AN fault forward

BN fault forward

Z1 BN fault Z2 ABN fault


Radial LineDifferential Algorithms

Differential Algorithms for phase selection:

if phase-to-phase fault AB SA = Σ∆VA x ∆IA and SB = Σ∆VB x ∆IB

if both directional are forward: forward AB fault

if both directional are reverse: reverse AB fault

if one of both directional is forward: A forward and B reverse = forward AN fault on protected line

Z1 BN fault

ABN BN

Z1 ABN fault

Trip three phase Trip single phase


Parallel LineCross Country Fault/Directional Decision


Parallel LineCross Country Fault/Directional Decision






Power Swing Blocking MiCOM P440


Power Swing Detection: Stable swing / Out of Step

In the case of a power swing, the apparent impedance first moves into the power swing boundary and later into the start-up characteristic. The speed of entry into the start-up characteristic is slower that in the case of a three-phase fault.

In case of out Of Step the loop cross the quad from +R to -R (opposite sign).

X lim

-R lim R lim

-X lim

R

R

X

X

Z4

Z3

Stable swing

Out Of Step

+R

+R

+R

-R


Unblocking for Faults During a Power Swing

During a power swing the absence of zero sequence current (no earth fault) and negative sequence current (no phase-to-phase) should be verified (in the event of asymmetry, a FAULT inception is detected with unbalance condition).

The power swing current should be smaller than a settable overcurrent threshold (if not, a three-phase FAULT inception is detected).

An unblocking timer can be set to remove the power swing block for persistent unrecoverable swinging.


Power Swing Blocking(Power Swing and Fault)

Powerswing

Fault

∆IPSB active PSB removed

50ms


Power Swing Blocking(Power Swing and Fault)


Unblocking for Faults During a Power Swing

P441/2/4 trips for all faults occurring during a power swing.

The power swing block is removed instantly for an unbalanced fault, on reselection by the phase selectors.

In the unlikely event of a 3 phase fault, a step change in ∆I resets the block.

Continuous ∆IDuring Swing

FaultInception

Minimal ∆IPresent


Power Swing Detection

∆R = 1,3 x tan (Π x ∆f x ∆t) x (Rlim² + Z²)/Z With:

∆t = 5ms, ∆f = power swing frequency (typical value 4Hz), Rlim = R34 resistance reach for zone 3 and 4,

Z = Z3 + Z4.

Typical value ∆R = 5 Ω by IN = 1A

∆R = 1 Ω by IN = 5A

Simplified equation: ∆R = 0.032 x ∆f x Z min Load


S1 Settings: ∆R/∆X Limits

Block zone

Number of swing cycles

S1-PSL Settings:

Distance Element unblocking on current presence

Power Swing DetectionOut Step Protection


Directional /Non Directional Overcurrent - MiCOM P440


Four independent stages: IDMT/DT stages 1 and 2

DT on stages 3 and 4

1 and 2 stages: Non directional

Directional forward

Directional reverse

IEC & IEEE IDMT curves

Directional/Non DirectionalPhase Overcurrent Protection

IEC CurvesOperating Time (s)

Current (Multiples of Is)

1000

100

IEC SIIEC VIIEC EIIEC LTS

0.1

1

10

100

1 10


Directional/Non DirectionalPhase Overcurrent Protection

Standard phase O/C protection: 0.08 x In - 4 x In stages 1 and 2

0.08 x In - 32 x In stages 3 and 4

TMS range: 0.025 to 1.2

Time dial: 0.5 to 15

Definite time: 0 to 100s

Adjustable reset time for stages 1 and 2

Emergency phase fault O/C on fuse failure (stages 1 and 2)

IEEE Curves

0.1

1

10

100

1 10 100Current (Multiples of Is)

Operating Time (s)


Time

Reverse Forward

Backup Phase Overcurrent Protection 50/51/67

Z1,tZ1

Z2,tZ2

Zp,tZp

Z3,tZ3I>1

Z4, tZ4

I>2

Two backup elements, IDMT and/or DT

Typical application shown above

DT delays can be reduced during VTS pickup, with overcurrent elements mimicking distance zone reaches

I>3 used for close-up fault (and SOTF/TOR)


VC VAVB

VABVBC

Backup Phase Overcurrent Protection 50/51/67

>

Direct Calculation A

IA

IDMT

Threshold detection

>IB

>IC

Direct CalculationB

Direct CalculationC

Direct CalculationAB

Direct Calculation BC

Direct Calculation

VCA

CA

>>

3P trip


I>4 Element: Stub Bus Protection

Busbar 1

Busbar 2

Open isolator

V = 0

I > 0

VT

Stub Bus Protection: I >4

Protection blocking using VTs


Negative Sequence DirectionalOvercurrent - MiCOM P440


Negative phase sequence overcurrent

Not dependent on voltage dip

Responsive to phase-phase or phase-earth faults

Directional capability

More complex setting calculation

Back-Up Protection


Thermal Overload DetectionMiCOM P440


Overcurrent protection designed for fault conditions

Thermal replica provides better protection for overload

Current based

Flexible characteristics

Single or dual time constant

Reset facility

Non-volatile

Current

Time

MiCOM-P540-217

Overload Protection (as P540) (1)


10000

1000

100

101 2 3 4 5 6

Trip time (s)

Current (multiple of thermal setting)

Single characteristic:τ = 120 mins

Dual characteristic

Single characteristic:τ = 5 mins

Overload Protection (as P540) (2):Dual τ Characteristic for Transformers


Overload Protection (3)

S1Settings:

PSL Cells - Input:

PSL Cells - Output:


Broken Conductor DetectionMiCOM P440


Majority of system faults are a result of short circuits

Easily detectable

Broken Conductor Protection

Possibility of open circuit faults exist

Difficult to detect with conventional protection


Existing detection methods:

Combination of under/overcurrent logic

Negative phase sequence overcurrent Consider suitability for all load conditions

P440 uses a ratio technique: I2 is high for open circuit fault condition

I1

Load conditions have minimal effect

Broken Conductor Detection


- Directional Comparison (DEF)- PW - IN> (4 thresholds)

Earth Protection:


Directional Earth Fault Protection (DEF)

High resistance ground faults Instantaneous or time delayed IEC and IEEE curves Single or shared signalling channel


Directional Earth Fault Protection Aided Channel DEF

High resistance ground faults

AIDED DEF: Instantaneous Parallel main protection to distance Single or three pole tripping Polarisation:

Zero sequence voltage Negative sequence voltage



Independent Aided Channels (1/2)

21

Sharedsignalling channel

67N

21

R AB Fault

67N

(21 keep priority on 67N)



Independent Aided Channels (2/2)

21

67N

21

67N

Independentsignalling channel

R AN Fault

(priority 21 = priority 67N)


MiCOM S1 Settings:

Directional Earth Fault Protection (DEF)


Two independent stages: IDMT/DT stage 1 DT on stage 2

1 and 2 stages: Non directional Directional forward Directional reverse

Polarisation: Zero sequence voltage Negative sequence voltage

IEC & IEEE IDMT curves

Directional/Non Directional Earth Fault Protection

IEC Curves

Current (Multiples of Is)

1000

100

IEC SIIEC VIIEC EIIEC LTS

0.1

1

10

100

1 10

Operating Time (s)



Standard earth fault 0.08 x In - 4 x In stage 1

0.08 x In - 32 x In stage 2

TMS range: 0.025 to 1.2

Time dial: 0.5 to 15

Definite time: 0 to 100s

Adjustable reset time for stage 1

Emergency earth fault O/C on fuse failure (stage 1)

IEEE Curves

0.1

1

10

100

1 10 100Current (Multiples of Is)

Operating Time (s)


Settings MiCOM S1:



PW: Zero Sequence Power Protection

The zero sequence power is maximum, at the fault and decrease along the network for being nul at the neutral transformers

That protection is delayed by a fixed timer to cover the 1P cycle & by an inverse timer to provide selectivity

RTE specifications

DJ DJ DJ DJ

VrmaxVrmin

3Io


Settings MiCOM S1:



PW Function: Characteristic

Idea: detection of Phase-ground resistives fault - not eliminated by the Distance Protection

Action: Trip 3P for Fwd resistive fault Tripping time with inverse curve


Ir(t) > Ir

Sr(t) = Vr(t)*Ir(t)*cos(phi-phi0) Sr(t) > Sr Tb

&

Zsp Start

Zsp TripIr(t)

Vr(t)

DéclenchementTriphasé

Zsp Timer Block

Ta 1


Distance Protection Algorithms

Directional Caracteristics in PW

R

X

Directional: -15°(since B1.3)

Z3

Z1

Z2

Z4

Zp

RCA axis +75°

Forward

Very resistant Fault


PW Function: Principle (1/4)

Calculation of residual Power Sr: Sr = Vr*Ir*cos(φ - φ0)

Vreff, Ireff = rms values of residual voltage & current.

Phi = phase shift value between Vr & Ir.

Phi0 = 255° (to get a sensibility max at 75°/ fixed line angle).

Trip Logic:


PW Trip

Tbase expiration

Tinv expiration



Signals associated to trip: CB trip order

Start Information Trip « Slow protection» (TC21) » information Trip Signal (for ADD - CB fail logic) Start Disturbance Directionnal Fwd Information

PW: Zero sequence Power Protection

PW Starting



Tripping Time: Tinv (Sr) = (k*Sref)/Sr compensated:

With : k = adjust time constant

Sref = Compensated Residual Power:

10VA for IN = 1A

50 va for IN + 5A

Compensated Sr is a variable compensated residual power calculation



S1 / WinEpac

With C2.0 Version

PW: Zero sequence Power Protection Micom S1 settings = WinEPAC Page (p4/4)


Under / Over VoltageMiCOM P440


Reasons for voltage deviations: Regulation problems

Load variation

Fault conditions

Requirements of protection depends upon application: Line or phase voltage measurement

Operation for all or any phase

Suitable time delays

Alarm/Trip

P440 under/over voltage elements suitable for all applications

Voltage Protection


Backup Phase Under-Overvoltage Protection 27 - 59

>VA / VAB

IDMT

Threshold detection

>

>

>VB / VBC

VC / VCA

Sel PhaseASel PhaseB

Sel PhaseC


Breaker FailureMiCOM P440


Circuit Breaker Failure (50BF) Two stage

Fast reset external initiation

Blocking scheme compatible

Reset By undercurrent By protection tripping By CB aux. contacts

From other device

Backtrip

Retrip

Trip

BFINIT


Breaker Failure Protection (50 BF)

CB Fail Signal(3)

87BBBusbar 1

Busbar 2

50BF

Other protection

CB Failed(2)

Trip Order(1)

Back Trip Order(4)

50BF 50BF

50BF

50BF


Non Protection Functions MiCOM P440


MiCOM P440 Non Protection Functions

CT / VT/CVT Supervision Communications

Autoreclose and Check Synch.

Bay Monitoring & Control

Self Diagnostics & Commissioning Tools

4 Setting Groups

Fault Locator

Measurements

Fault AnalysisTools

Materials


Setting GroupsMiCOM P440


Spare Line Relay Applications (Transfer Bus)

Use of Alternative Setting Groups

2 31 4Four groups available

Settingselectioninputs

SCADAor PLC


VT/CVT/CT Supervision MiCOM P440


VT Supervision (1)

AlarmsEvent recordBlockingAdaptive setting

1φ and 2φ logic

3f on load logic

3f on energisation

logic

MCB digital input

VTS

A

B

C


VTS alarmVTS blockLCDEvent records

Loss of all 3 phase voltages under load

P440

&

Voltagecollapse

VT Supervision (2)

∆I


VTS alarmVTS blockLCDEvent records

Loss of all 3 phase voltages upon line energisation (via PSL)

P440

&

NoVoltage

VTS I>Inhibit

VT Supervision (3)


CT Supervision

A

B

C

IO

VO

& T

AlarmsBlocking

Event record


Capacitive Voltage Transformers Supervision - (CVTS)

Characteristics

Principles

MiCOM S1

CVTS Function

Since version B1.0


Function CVTS: Characteristics


TCT Anomaly

Voltage control

TCT activation function

Threshold Vr

Vr > Vr Threshold Vr

Va

Vb

Vc

0 tTCT

Uab > 0.8*Un

Uab < 0.4*Un

Detect internal failure of CVT by using the residual voltage measurement

Signaliasation by output contact «TCT anomaly»


CVTS Function: Principle (1/1)

Monitoring of Vr threshold pickup (settabled)

Monitoring of P/P U AB voltage (with hysteresis) fixed: Set: 80% Un Reset: 40% Un

Signal of delayed alarm CVTS (settabled from 0 to 5mn, by step of 30s)


TCT Supervision

Fault

TCT Anomaly

indication


Function CVT: Page MiCOM S1/WinEPAC



Supervision: VTS & CTS & CVT

Settings MiCOM S1:


Fault Locator MiCOM P440


16% 3.8Ω 16km10miles

Distance to Fault Locator

With Mutual Current Compensation


Autoreclose and Check SynchronismMiCOM P440


Integrated Autorecloserwith Voltage Control

Up to 4 cycles of reclosing: First fast cycle can be single phase

(P442 - P444)

3 time delayed cycles

Starting selection elements/autorecloser interlock


Voltage control function allows: Autoreclose on live line / live bar

Autoreclose on dead line / live line

Autorecloser on live line / dead bar

Safety checking prior to manual close authorisation (remote or local)

PSL dedicated to increase the wait window to close conditions

Integrated Autorecloserwith Voltage Control


CB Control & Monitoring MiCOM P440


Supervision

Trip circuit supervision CB state CB supervision

Number of trip Sum Ix, 1.0 < x < 2.0 Operation time


Control of Bay

Circuit breaker control

Multiple settings groups (4)

Programmable scheme logic


A User’s View - Interface MiCOM P440

Programmable Scheme Logic - Settings - Distance Com...


Edition/Modification of settings and text in the protection

Edition/Modification of logic schemes

Extraction of event log records Supervision Extraction of disturbance

records Analysis of those records

MiCOM S1 V2

MiCOM S1 (P20-P30-P40) Setting Software


Menu System

Alarmmessages

Frequency System Three-phasevoltage

Line

Argument. of kZm

Column 1 Data

System

Language

Password Niv.2

Column 2Visu. Record.

Select.Event

Reset Indication

C

C

Other title of columns Group 4Column n

Prot. Distance

Date & Time


Interface HMIPSL (Programmable Scheme Logic)

MiCOM P440


Programmable Scheme Logic (Introduction)

User programmable scheme logic

Timers

Relay contacts

LED’s

Protectionelements

Fixed scheme

logic

OptoGate Logic


Programmable Scheme Logic (1/9)

Timers

Protectionelements

Fixedscheme

logic

Gate Logic

In

Out

Programmable Scheme Logic


TOR opto-isolated input selected from the list

Possible Choice with S1(hysteresis & filtering):

Programmable Scheme Logic (PSL) (2 /9)


TOR opto-isolated input added to an internal DDB of the relay

and selected in the list



Programmable Scheme Logic (PSL) (4 /9)One more timer

Link throught:

Led - Output relay


Different options by element:

Different options by PSL:



Up to 256 gates

Logic Functions Gate OR Gate AND Reversers Timers


Peer to peer com:InterMicom

GooseControl Input...


P440

+

-

52 b52 a

CB coil

Trip Trip CircuitSupervision

Alarm



Customisation

256 gates 8 timers Feedback

Default schemes Validity checks Event driven

Trip Circuit Monitoring Using Programmable Scheme Logic (8/9)


Blocked Distance ProtectionUsing Programmable Scheme Logic (9/9)

Established technique providing:

Improved BB fault clearance times

In order to facilitate this function, P440 provides:

Directional start signals (Directional Comparison Scheme)

Block Z1element

Feeder 1

Incomer

Feeder 2 Feeder 3


HMI Interface MiCOM P440 Measurements (Monitoring)


MeasurementsMiCOM P440


Programming (set & PSL) of relays

Extraction of information from relays

Assists with commissioning(fault record, event,monitor control)

Supports analysis of power system disturbances (comtrade format)

MiCOM S1 V2MiCOM Support Software

Compatible with existing

products using the Courier language


MiCOM Support Software


Measurements (1)

Possibility to extend measurement To remove subsidiary instrumentations Reduces wiring and space Assists with commissioning Analysis of power system

10 A


IA Amplitude 980.2A

Instantaneous Measurements:

Phase to phase voltage and single phase voltage

Residual voltage (3Vo) Residual and current phase Positive , negative and zero sequence

current and voltage Frequency Active, reactive and apparent power Active and reactive energy Check Sync Voltage Zero-phase-sequence current of parallel

line (used for the mutual compensation) Possibility to print a report

Integrated Values: Peak, average & Rolling

demand: Ia Ib Ic W VAr Wh VArh

Measurements (2)


HMI Interface Events - Disturbance Records

MiCOM P440


Diagnostic’s HelpMiCOM P440

ZGraph

Event record

Fault record

Disturbance Recorder


Diagnostic’s Aid

Complete fault display report Time tag at 1ms Recording criterions choice Non-volatile backup memory Easy access via User ’s interface

Event log Fault report Disturbance records Fault locator Trace


Events: 250 records (500) Non-volatile memory

Fault report: 5 last faults Non-volatile memory

Event Log

Start A 10msFault recordI1> 10msV< 15msTrip ABC 15msCB52 Open 60ms


Disturbance Records

Pre-fault Post-fault

8 Analogue channels 32 Digital channels Configurable record criterion Variable trigger point 24 Samples per cycle (no compression) 28 Records (3sec each) Record duration of 10.5s Non-volatile memory Extended recording time MiCOM S1 saves file in the

COMTRADE format


Self-Diagnostics & Commissioning MiCOM P440


Self Diagnostics & Commissioning

Commissioning available to user Inputs Outputs Internal states Measurements

Event driven maintenance Improved availability

Power-on diagnostics Continual self-monitoring


Communications MiCOM P440


Local Communications

Settings Records Control Measurements Commissioning Maintenance Menu text


Remote Communications MiCOM P440


Courier (front/rear1/2nd rear)

IEC60870-5-103 DNP3.0 MODBUS UCA2.0 IEC61 850 -8-1(Soon)

Digital Control Systems

Remote Communications


Hardware modification to integrateEthernet (UCA2 and IEC61850)

Available with protocols UCA2 & IEC61850

Selection of Hardware Options

Available as a prototype (n units <10 by order)








Ethernet Interface (P*40)

Fibre/copper ports available

10MHz/100MHz options for fibre

Indication of Link and activity

MAC address is unique hardware address of card

Used by UCA2 and IEC61850


Typical Example Showing Use of Two Rear Comm. Ports

R.T.U.

Modem

POW

ER S

UPP

LY

CEN

TRAL

PR

OC

ESSO

R

MiCOM S1 software

CK222Modem RS232RS232

RS485

RS485Com 2Com 1

CK222Multiple rear ports

CK222 not needed where either MODEM or RTU accept RS485

directly

RS232 Front port connection


UCA/IEC61850NCIT


Future Trend

61850-9-1

61850-9-261850-8-1

61850-8-1

Bay Level

Protection Control

Station Level

Function A Function B

HV Equipment

Bay Level

Protection Control

HV Equipment

3

1

3

16 6

9

4 5 4 5

8

7 Technical Services


IEC61850 Compliance Levels - Comm. Protocols

Strategy for Protection Range

GOOSE I/O

TIME SYNC

SETTINGS

DISTURBANCERECORDING

COMMANDSOne Box Solutions

METERINGReal Time Values

IEC61850 Full

IEC61850 Extended

IEC61850 Basic

DATAEVENTSREPORTS

P30/P40: Ethernet board is already available (UCA2 protocol implemented for NiCAP project)

IEC61850 Basic: Available

IEC61850 Extended: End 2005 ...

IEC61850 Full: TBD

Remote setting can be done either over Ethernet or via 2nd rear port

P44x: Sept 2005


MiCOM S1 Based on IEC61850

P20/30/40Settings File

MiCOM S1

IEC

6185

0 / E

ther

net b

ased

Rea

r Por

t Com

mun

icat

ion

IEC103/Modbus/Courierbased Front & Rear Port

Communication

High-LevelProcedures

RS232 / RS485 / ...

IEC60870-5-103CourierModbus

TCP/IP EthernetData ModelProcessing

P20/30/40 DataModels

S&R-xxx joins Ethernet / IEC61850

DNP3


CIGRE Demo


MU-IEDs Typical Architecture

Distance P44XCS/AR/Backup

Busbar P742/3BF

Line Diff P54X PQMTFR M87x

(80 or 256 s/cycle)(80 or 256 s/cycle)(80 or 256 s/cycle)

MU-BB VT1

MU-BB VT2

MU-Main 1 MU-Main 2 MU-MQ

Redundancy


IEC61850

Identified customers with a strong IEC 61850 preference (part of their specifications) once the standard is available (end 2003): ELIA

NGT

Vattenfall

RWE

SIG

TENNET

SHELL

SOLVAY

SONELGAZ

ESKOM

Hydro-Quebec

AEP

TERNA

RTE

ISA

EVN

IECo

PowerGrid (India)

Volkswagen

etc… Transmission & large industries, first in Europe but expanding to Rest Of the WorldWindfarm to come through IEC 61400 (IEC 61850 derivative: new objects)


IsThere a Need for Inter-operability Inside of a Substation ?

Non exhaustive list of existing examples includes: Use of different protection manufacturers for a feeder

protection (security)

Re-use of existing or qualified relay (line differential)

Use of an imposed HMI

The current practice is to use the following protocols IEC 60870-5-101/103/104, DNP3, OPC

IEC 61850 could provide further benefits Peer-to-peer (automation)

XML exchanges (configuration)


What are the Advantages to Use IEC 61850 Instead of Existing Technologies ?

Reduced installation costs

Reduced configuration costs

Reduced maintenance costs

Improved functionality/network reliability

Reduced effects of substation transients on protection and control applications

Adaptive applications

Customer Requirements:


Communications based interface between the sensors and the IEDs

No hard wires - fiber only

Self-description of the IEDs

Distributed peer-to-peer communications of state changes

Distributed peer-to-peer communications of analog and sampled values

What are the Advantages to Use IEC 61850 Instead of Existing Technologies ?

Solutions:


InterMiCOM

(17pages)


InterMiCOM Predecessor

LFZP141Generat

orProtecti

on

InterMiCOM

HSDI Digital Intertripping• CRC-8 polynomial for optimum security

LFCB, PQ741 and MiCOM P540 Current Differential• Use of intertrip and PIT commands between line ends

F + 0

RESET

ALARM TRIPHEALTHY

F E D C B A 9 8 7 6 5 4 3 2 1 0

SETTING GROUPFAULT No

AUX TIMER

AUX 1AUX 2AUX 3

A B

C*-*--*

K-Series Overcurrent• Proven logic interconnectionschemes between adjacent relays

MODULEX MX3 Line• In-service inter-relay schemes using LONWORKS


InterMiCOM?

Px40/Px30

01100011

01001100

Px40/Px30

Tx

Tx

Rx

Rx

What is InterMiCOM?


InterMiCOM

InterMiCOM on Distance Protection Devices P430 (Example)

Digital communication linkfor the transmission of protective signals


InterMiCOM

“Point to point” transmission of 8 digital signals

User independently settable signals

Common message format across 30 and 40 series

High security and fast operating time

Testing facilities

Channel statistic

Key Features


InterMiCOM

To respond to increased market requirements for better relay

interconnections that enhance applications

To speed up the transfer of commands at high security

To reduce wiring and auxiliary equipment

To provide less dependency on power line carrier communications channels

To ease an integration of other relays into MiCOM schemes

Main Benefits


InterMiCOM

Possible InterMiCOM connections between 40 series relays

MODEMMODEMRS232 RS232

<15m <15m

8 signals

8 signals

RS232 RS232

<15m max

8 signals

8 signals

Via modem (opto links or telephone lines or VF or wireless Microwave link)

Direct connection between relays (unlikely configuration)

Different ways of 40 series relay connections for InterMiCOM application


InterMiCOM

Possible InterMiCOM connections between 30 series relays

MODEMMODEMRS485 or FO RS485 or FO

<1 km <1 km

8 signals

8 signals

RS485 or FO RS485 or FO

<1 km max

8 signals

8 signals

For distance above 1km

Direct connection between 30 series relays

Different ways of 30 series relay connections for InterMiCOM application


InterMiCOM

Possible connections between 30 and 40 series relays

MODEMMODEM

RS485 or FO RS485

<1 km <15m

8 signals

8 signals

RS485 or FO (850nm)

<1 km max

8 signals

8 signals

For distance above 1km

Direct connection between 30 series relays

Different ways of 30 and 40 series InterMiCOM connections

RS485/RS232(CK222)

orFO/RS232

RS485/RS232(CK222)

orFO/RS232

<15m maxPx30 Px40

Px40Px30


InterMiCOM

example of other protections integration into InterMiCOM

via MiCOM PSL

F + 0

RESET

ALARM TRIPHEALTHY

F E D C B A 9 8 7 6 5 4 3 2 1 0


AUX TIMER

AUX 1AUX 2AUX 3

A B

C*-*--*

PSLMODEMMODEMRS232 RS232

<15m <15m

DIT

DIT

KBCH

Px40

Buchholz

F + 0

RESET

ALARM TRIPHEALTHY

F E D C B A 9 8 7 6 5 4 3 2 1 0


AUX TIMER

AUX 1AUX 2AUX 3

A B

C*-*--*

KBCH

Px40

PSL


InterMiCOM

Underreach protection: Intertripping underreach protection (IUP) (IEV 448-15-12)

Direct underreaching transfer trip protection (USA) (DUTT)

Permissive underreach protection (PUP) (IEV 448-15-11)

Permissive underreaching transfer trip protection (USA) (PUTT)

Accelerated underreach protection (AUP) (IEV 448-15-13)

Protection using Telecommunications acc to IEV 448-15


InterMiCOM

Overreach protection:Permissive overreach protection (POP) (IEV 448-15-16)

Permissive overreaching transfer trip protection (USA) (POTT)

Blocking overreach protection (IEV 448-15-14)Blocking directional comparison protection (USA)

Protection using Telecommunications acc to IEV 448-15

ForFor protection schemes using telecommunication a binary signal is protection schemes using telecommunication a binary signal is transmitted from one end to the other end of the protected line.transmitted from one end to the other end of the protected line.


InterMiCOM

Blocking signals

Permissive Intertrips (PIT)

Direct trips (DIT)

InterMiCOM signals (commands)

Three teleprotection command levels are supported by InterMiCOMThree teleprotection command levels are supported by InterMiCOM


InterMiCOM

Speed (⇒ transmission time):Time elapsed between the instant of change in state at the command input and the instant of the corresponding change in state at the command output, excluding propagation time

Security:Security relates to the ability to prevent interference and noice from generating a command at the receiving end when no command signal is transmitted.

Dependability:Dependability relates to the ability to issue and receive a valid command in the presence of interference and/or noise.

Characteristics of Teleprotection Systems acc to IEC 60834-1

CommandCommand type teleprotection systems have to assure the characteristics type teleprotection systems have to assure the characteristics ‘speed‘, ‘security‘ and ‘dependability‘ to an extremely high degree.‘speed‘, ‘security‘ and ‘dependability‘ to an extremely high degree.


InterMiCOM

Speed

DependabilitySecurity

Blocking

Direct

PermissiveAccelerated

60 ms

40 ms

20 ms

10-610-4

10-2

10-610-4

10-2

Requirements on Teleprotection Systems acc to BS 7494-1


InterMiCOM

Message Format

each message consists of:• start bit-field• address bit-field (R)• 8 user settable command bit-field (B1-B8)• CRC calculation bit-field• stop bit-field

start B1 B2 B3 B4 B5 B6 B7 CRC stop

BLOCK or DIT PIT or DIT

B8R

InterMiCOM message

Each B1 - B4 can be Each B1 - B4 can be set independently to either BLOCKING SIGNAL or DIT.set independently to either BLOCKING SIGNAL or DIT.Each B5 - B8 bit can be set independently to either PIT or DIT.Each B5 - B8 bit can be set independently to either PIT or DIT.


InterMiCOM

Signal selection, one way transmission shown for simplicity

Simplified example that shows assignment of digital signals 4 and 6 Simplified example that shows assignment of digital signals 4 and 6 at local relay and their transmission to the remote relay at local relay and their transmission to the remote relay

46

LOCAL relay(sending end)

46

REMOTE relay(receiving end)

comms

Tx Rx

link link


InterMiCOM - Modem Selection

RS232 Analogue Channel

Data Rate @ theRelay Interface

(ITU-V)Standard

BLOCKINGTransmission

Time

PITTransmission

Time

DITTransmission

Time1200 V.22 8.33 ms 25.00 ms 25.00 ms

2400 V.22 bis 4.16 ms 12.50 ms 12.50 ms

4800 V.27 2.08 ms 6.250 ms 6.250 ms

9600 V.32 1.04 ms 3.125 ms 3.125 ms

19200 V.32 0.52 ms 1.562 ms 1.562 ms


Conclusion MiCOM P440


Versatile distance relay for all MV→EHV applications


Overhead line and/or cable applications

Full complement of distance and DEF schemes



Integrated four shot autoreclosure with check synch

P440 Summary


Summary of P440 Functions

21G Ground distance protection, 3forward elements, 1 reverseelement, 1 selectable element,quadrilateral zones.

21P Phase distance protection, 3forward elements, 1 reverseelement, 1 selectabe element,quadrilateral zones.

85 Channel-aided protection.50 Phase overcurrent, High set,

for Stub bus application.67/46

Negative sequence overcurrent

49 Thermal Protection - overload

50/27 Switch onto fault and trip onreclose

50/51 Phase overcurrent, DT orIDMT

50/51NGround overcurrent, DT orIDMT

51FF Fuse failure overcurrent67 Phase directional overcurrent67N DEF, communication aided32N Power swing detection, used

to selectively permit or blocktripping

68 Power swing blocking -Out of step tripping(using PSL)

VTS Voltage transformer supervision

CVTS Capacitive Voltage transformer supervision

CTS Current transformer supervision

50BF Circuit Breaker failure46BC Broken conductor detection25 Check synchroniser79 Autorecloser59,27 Overvoltage/Undervoltage


Our Answers to Your Requirements MiCOM P440


Personalised Protection

MiCOM: The Essential Link - Strength & Flexibility

Reliable protection scheme

Adaptable to specific network substation design

Comprehensive integral protection functions

Standard logic schemes can be selected

Powerful diagram based programmable scheme logic

Large range of signal selections

3 Models (input/output)

Your Requirements Our Answers


Network Reliability

Maximum continuity of supply

Immediate alarms

Load avoidance

Integral 4 shot autoreclose

with synchronism check Switch on to fault

Minimise damage Continuous self check Watchdog contacts Alarms via communication

system Power swing

blocking/tripping Quadrilateral

characteristic




Staff

Standard MiCOM range user interface (know 1, know all)

Standard MiCOM software support S1, S10

Standardized documentation

Combination of L range style front panel & K range menu structure

Fast training

High competence

Familiar & easy interface




System Management

CB fail system Local or remote CB control 250 event records 20 x 10.5 second

disturbance records Fault locator CB monitoring

Number of operations Operating time Operation duty

Circuit breaker control

Fault diagnosis

System monitoring




Total Feeder Protection

Distance Under & Over voltage DEF, Sensitive DEF - Positive

& zero sequence polarising Directional negative sequence

overcurrent 5 zone characteristic Weak infeed scheme Circuit breaker fail CT/VT supervision

Forward & reverse detection

Sensitive fault detection Back up protection

Primary plant failures CB - VT - CT




Relevant Information Available/Understandable

Language selection Customised text facility Assignable LED Assignable outputs Programmable logic for

LEDs& outputs

Windows & graphical user interface

S1, S10 PSL Editor

Your own language

Your own text

Indications relevant to the substation




Availability of Information

Instantaneous DATA Stored DATA Accurate DATA Synchronised DATA Long term DATA

retention Fast information access

On Line measurements <1% accuracy

250 stored events 20 stored disturbance

records Range of communication

options 2nd rear port (Courier) IRIG-B time

synchronisation Fault locator Fast access time Battery backed realtime

clock




Logistics

Compact size 8 case or enhanced size 12 or 16

Dual CT ratings or IEC 60044-8 fibre optic input for NCIT

3 voltage ranges

Internal field voltage

Minimum stock

Minimum panel space

Suitable to all substation




Reliable Operation

>10 years experience of algorithm

Used from MV to EHV networks

Multiple kZo residual compensation factors

Stub bus protection 4 setting groups Hybrid line facility High performance delta

algorithm (patented) Starting Phase selection Directional decision

Proven performance

All networks

Adaptive configuration



Bye !


Areva

Documents

proven installed

bnc rx1 tx1

programmable

weak infeed

weak infeed

alternative

bnc sk4 sk5

earth loop