distributech 2015 taking interoperability to the next level

1DISTRIBUTECH – San Diego Convention Center – San Diego, CA, USA – February 3, 2015

Riel Station

Taking Interoperability to the Next

Level

DISTRIBUTECH 2015

San Diego Convention Center, San Diego, Ca, USA

February 3, 2015


Project Background


Manitoba Hydro – Fast facts

● 548,700 electric customers

● Installed based capacity of

5,685 MW mainly hydraulic

● Service Area: 650,000 km2

● Capital assets in service

exceeding $15 billion

● Exports electricity to three

wholesale markets in

Canada and the mid-

western United States


Riel Substation

● Sectionalize 500 kV line to

Minnesota

● Sectionalize 2-230 kV

network lines

● In-service-date Oct 2014

● Future site of Bipole III

(ISD 2018)


Riel Substation Site


Technology

● Standard is A & B protection

relays from different vendors

● Utilized A & B control

systems and networks

● Utilization of IEC 61850

GOOSE messaging for

protection & control

6


Project Overview


Scope of Work

● Complete solution for Substation Automation (Control & Protection) – Total 77

Panels● Management, Engineering, Configuration, manufacturing, FAT, and Commissioning SAT

● Based on Schneider Electric PACiS (Protection and Control Integrated System)

& SUI (Substation User Interface) Solution.

● High IEC61850 Network Redundancy IEC61850 (Dual-homing + RSTP).

● One configuration software for all substations, with configuration of all bay

Controllers, Protective relays (reports) and HMI’s.

● NERC-CIP Compliancy.

● Capable to fulfill current and future’s requirements.● Thanks to IEC61850, today is a reality – Phase II


Panels 500kV/230kV

500kV (Scope: detailed design, Manufacture, FAT, SAT support)

● 10 protection panels (16 Relays) + 2POW (6 IEDs), 1 Meters (3 IEDs) + 1 DR ( 2IED) + 1 Tap Controller

● 4 Control Panels (6 C264)

● 2 Server Panels (2 PACiS OI + 2 gateway+ 2 Engineering work stations)

● 2 Alarm annunciators (3 C264)

●Total= 23 panels

230kV (Scope: detailed design, Manufacture, FAT, SAT support)

● 18 protection panels (44 Relays) + 2 DR (2 IEDs), 6 POW (8 IEDs)

● 10 Control Panels (14 C264)

● 4 Server Panels (4 PACiS OI + 2 gateway + 2 engineering work stations)


● Total= 44 panels


Panels 12.47kV and IEC61850

12.47kV (Scope: detailed design, Manufacture, FAT, SAT support)

● 4 protection panels (10Relays).

● 2 Control Panels (2 C264).

● 2 Server Panels (2 PACiS OI + engineering work stations).


● Total: 10 panels

IEC61850 (Scope: Goose implementation, Test philosophy, Net. topology)

● 500kV and 230kV: 50BF entirely implemented with goose.

● 12.47kV: 50BF and Bus bar protection using blocking schemes.

● Dual redundant network using dual homing and RSTP protocol to enhance network reliability


General System Architecture

● Two different systems distributed among several buildings to:

● Supervise,

● Control,

● Protection system

● Only one supervising ring with all the information coming from different

voltage levels 12.47/230/500 kV, and the control as per voltage level and

system A or B.

● All protections and bay controllers use IEC61850 to:

● « Service report» sent directly to the control system.

● GOOSE messages between relay for protection functions.

Building

CBF1

Bay 3 & Bay 4

Busbar A1 & B1

Transformer SST1

Bay 9 & Bay 10

Busbar A2 & B2

Transformer SST2

Bank 1

Bank 1

M602F & REACTOR

D603M & Bay 1

Capacitor Bank 46kV

Bank 1

M602F & REACTOR

D603M & Bay 1

Capacitor Bank 46kV

Revenue Metering

SYSTEM « A »

230 kV

SYSTEM « B »

230 kV

SYSTEM « B »

500 kV

SYSTEM « A »

500 kV

Gateway

IEC/IEC

Building

CBF3

Building

CBF2

Bay 3 & Bay 4

Busbar A1 & B1

Transformer SST1

Bay 9 & Bay 10

Busbar A2 & B2

Transformer SST2

Bank 1

Building

CBF4

Building

CBE1

Building

CBE2

Building

SS1LBuilding

SS2L

SST1 SST2

GatewayDNP3.0

H162H162H162H162H162H162

RSG2100

RSG2100 RSG2100

RSG2100RSG2100

RSG2100

RSG2100

H162 H162

Gateway

IEC/IEC

Gateway

IEC/IECGateway

IEC/IEC

Gateway

IEC/IEC

Gateway

IEC/IEC

Gateway

IEC/IECGateway

IEC/IEC

RSG2100

HMI HMI HMI HMI HMI HMI HMICentral PC

To Industrial Data Network

(Remote access for Engineering)

GatewayDNP3.0

GatewayDNP3.0

To DNP3.0 SCADA

(Main) - 230kV

To DNP3.0 SCADA

(Secondary) - 230kVTo DNP3.0 SCADA

(Main) - 500kV

To DNP3.0 SCADA

(Secondary) - 500kV

12,47 kV

HMI


● Time synchronization via

GPS, broadcasted using

SNTP

● System compliant with

NERC-CIP Standards

● Distributed Logics & interlocks, Control Uniqueness in a per VL basis.

● Synchro-check function integrated in Bay Controller

● Future expansion consideration (actually 40% of final project)

System Characteristics

Redundancy notion at all levels:

• Acquisition: bay controllers and protective relays

• IEC61850 network: SE Dual homing + RSTP

• Different Point-of-Control at different levels

• SCADA, redundant DNP3.0 link per voltage level


SAS Architecture

LEGEND

C264 or

Bay controller

IED

(Protection Relay)

Ethernet Switch

Ruggedcom

RSG2100

Gateway A300

(IEC/IEC or DNP 3.0)

HMI

(Pacis OI Server & Client

Or Pacis Engineering

Workstation)

Ethernet

Switch

MiCOM H36x

GPS SNTP

(Not provided

by Areva T&D)


• C264: Bay Controller

• RED 670 Line Protection

• SEL 487E: Transformer Diff Relay

• SEL487B: Busbar Protection Relay

• SEL421: Line Protection Relay

• GE D90+: Line Protection Relay

• SEL451: Stand Alone Protection Relay (cap

Bank)

• P991: Test Block

• P992: Multi Finger Plug

• MVAJ105: Hand and electrical reset trip relay

• C264: Bay Controller

• P546: Universal Line Protection for Breaker

and Half application, with current diff and

sub-cycle distance elements

• P643: Transformer or Reactor Protection

• P746: Busbar protection for 8 feeders

• P143: Feeder Management Relay

• P991: Test Block

• P992: Multi Finger Plug

• MVAJ105: Hand and electrical reset trip relay

Third Party products:

• TAPCON 260: voltage regulator from MR Rheinhausen

• TESLA 3000 from ERLPhase

• RSG2100/2200: Ruggedcom Switch

• ION 7650: Revenue Metering from Schneider

Primary Protection Backup Protection

Interoperability


230 kV Protection System


230 kV, SLD, CT & PT and Protection Zones

52-16F

52-15F

52-14F

52-13F

52-17F

52-18F

52-19F

52-20F

52-12F

52-11F

52-10F

52-09F

52-5F

52-6F

52-7F

52-8F

230kV Bus B1

230kV Bus A1

52-41F

52-24F

52-23F

52-22F

52-21FBAY 2 BAY 3

BAY 4 BAY 9 BAY 10

50:5

50:5

230kV Bus A2

M32R

M33R

M86V M87V

Bank T71

52-

121L

52-

221L

12.47kV

12.47kV

52-16F

52-15F

52-14F

52-13F

52-17F

52-18F

52-19F

52-20F

52-12F

52-11F

52-10F

52-09F

52-5F

52-6F

52-7F

52-8F

230kV Bus B1

230kV Bus A1

52-41F

52-24F

52-23F

52-22F

52-21F

11T87A/SST2

11L

21A

/L1

8F

11L

21A

/L2

2F

11L

87

A/L

15

F

11

L8

7A

/L9

F

11T87A/SST1

3

1

31

3 3

3 3

33

3 3

3 3

BAY 2 BAY 3

BAY 4 BAY 9 BAY 10

600:5

50:5

4000:5

4000:51

1B

87A

/SS

T1

V-18F V-22F

4000:5

4000:5

4000:5

4000:5

4000:5

600:5

50:5

4000:5

4000:5

4000:5

230kV Bus A2

M32R

M33R

M86V M87V

Bank T71

11

B8

7A

/SS

T2

4000:5

1

3

52-

121L

3

1

3

52-

221L

12.47kV

12.47kV

T7

1A

3

11B87A/B1F

11B87A/A1F11B87A/A2F

52-16F

52-15F

52-14F

52-13F

52-17F

52-18F

52-19F

52-20F

52-12F

52-11F

52-10F

52-09F

52-5F

52-6F

52-7F

52-8F

230kV Bus A1

52-41F

52-24F

52-23F

52-22F

52-21F

11T87A/SST2

11L

21A

/L1

8F

11L

21A

/L2

2F

11L

87A

/L1

5F

11

L8

7A

/L9

F

11T87A/SST1

3

BAY 2 BAY 3

BAY 4 BAY 9 BAY 10

600:5

50:5

11B

87A

/SS

T1

4000:5

600:5

50:5

230kV Bus A2

M32R

M33R

Bank T71

11B

87A

/SS

T2

4000:5

52-

121L

52-

221L

12.47kV

12.47kV

T7

1A

11B87A/B1F

11B87A/A1F11B87A/A2F

M87VM86V

230kV Bus B1


Bay 2 Actual Protection Scheme (Phase 1)


Bay 2 Protection Scheme (Expansion)


12 kV Protection System


Actual 12.47kV SLD/Protection System


12.47kV Protection system specification.

● Customer requirements.

● Highly segmented BB.

● Conventional functions: 50/51, 51/51N, 50BF.

● Customer asked: What can we do to clear Bus faults without using

conventional BB protections (costly at this voltage level) or partial BB

protection?

● Basic design study.

● After studding the problem and cost restriction we chose the

implementation of BB protection with blocking scheme. The blocking is

performed by means of Goose messages allowing us a fault clearance time

of 50-55ms and an appropriate selectivity.


BB Blocking Scheme, fed from SST1

52-106F

52-109F

52-115F

52-122F

52-121F 11F/121L

11F/106L

11F/109L

11F/115L

11F/122L

FW FW

52-215F

52-209F

52-206F

52-222F

52-221F11F/221L

11F/215L

11F/209L

11F/206L

11F/222L

FWFW

52-

8F

52-

7F

A1 B1 52-

18F

52-

17F

A2 B1

11T87A/

SST1

11T87A/

SST2

50/5

1

BL

k

BL

kB

Lk

50B

F

11B87A

/SST1

50/5

1

BLk BLk BLk

BL

k

50B

F

50B

F

50B

F

50BF50BF

50B

F

BL

k50B

F

50BF

IEDProtection Relay

50BF Goose

Blocking GooseWired Trip

Wired BF


Testing in a IEC61850 Environment

● Customer requiremets.

● Physical blockage of goose

messages by means of test

switch.

● Indication to the Control system

that a specific relay is under

test.

● Ability to Block subscribed

messages in the relay under

test.

● Ability to block published

message at the subscriber level.

DDB #064En. Subs. Goose

DDB #065En. Pub. Goose

DDB #1888Virtual Output01

DDB #1889Virtual Output02

Allow Goose Messages from this relay to enter

the logic of the other relays

Inputs for TEST MODEUnder Test

&

DDB #205I>3 Timer Block

DDB #210IN1>3 Timer Blk

DDB #834Virtual Input 3


DDB #034BLK I>3 frm 106L

DDB #035BLK I>3 frm 109L



&

&

Blk I>3 from 106L

Allow Gosse from 106L

Blk I>3 from 109L

Allow Gosse from 109L

1

Bus Bar Blocking Scheme

1

2

TST(Blk I>3 from 106L)

&DDB #851Virtual Input 20


TST(Blk I>3 from 109L)

&

DDB #032Sub Goose Enable


Conclusion● More than one thousand signals involved in protection schemes and system

control implemented in IEC61850 with GOOSE and reports messages for the

three voltage levels.

● Significant reduction in wiring between panels and buildings, that lowers the

risk of bad connections.

● In a traditional wired substation inter-wire faults are detected once the

functionality is not available. In IEC61850 substations FO faults are signaled

immediately avoiding potential malfunctions.

● The usage of IEC61850 allowed MH to engineer substation expansions without

inter wiring complications. This minimizes down time and potential wiring

errors. Substation upgrades may be securely tested in an emulated

environment.

● Improved system reliability due to the use of:

● System A & B protection relays.

● Protective relay with dual redundant fiber ports fitted.

● Dual Homing mechanism with 0 changeover time.

● Dual ring switches with eRSTP protocol .


Thanks for your attention

Daniel Boucher, Utility Segment Manager

[email protected]

Schneider Electric, North America Operations

Claudio Rimada, Senior Engineering Manager

[email protected]

Schneider Electric, EAC-NAM

mailto:[email protected]

mailto:[email protected]

distributech 2015 taking interoperability to the next level

Technology

support18 protection

support10 protection

support4 protection

panels iec61850 scope

ieds10 control panels

panels 500kv230kv500kv

c2642 server panels

c2644 server panels