1. GRID PROTECTION
SYSTEMS – New
Technologies

2. © Siemens Ltd 20122
Wide Area monitoring
Grid Stability & Security
Protection Systems
Power System Overview
Table of contents
Feedback

3. © Siemens Ltd 2012Page
Energy systems worldwide are changing…
There is nothing
permanent except change

4. © Siemens Ltd 2012
Capacity problems are posing economic risks…

5. © Siemens Ltd 2012
The Smart Grid by Siemens is part of the answer.
Constant energy
in a world of constant change

6. © Siemens Ltd 2012
Changing infeed patterns are challenging existing
grid infrastructures
Weekly loading of a transformer station in the rural area of
LEW-Verteilnetz GmbH – 2003 and 2011
Source: LEW
Load in kW
200
100
0
-100
-200
-300
12:00 0:00 0:00 0:00 0:00 0:00 0:00 0:0012:00 12:00 12:00 12:00 12:00 12:00 12:00
Load profile 2003 Load profile 2011

7. © Siemens Ltd 2012
Challenges in
changing energy
systems
Significant changes in energy systems require
a new Smart Grid infrastructure
Renewable and
distributed
generation
Limited
generation and
grid capacity
Aging and/or
weak
infrastructure
Cost and
emissions of
energy supply
Revenue losses,
e.g. non-
technical losses
Smart Grid
Solutions
Balancing
generation &
demand, new
business models
Load
management &
peak avoidance
Reliability through
automatic outage
pre-vention and
restoration
Efficient generation,
transmission, distri-
bution &
consumption
Full transparency
on distribution level
and automated loss
prevention
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Transmission Applications

9. © Siemens Ltd 2012
Transmission Applications
Aging and/or weak
infrastructure
Trends
Integration of
renewables
Grid capacity /
Reliable energy supply
Regulations
Customer
challenges
Integration of renewables:
E.g. Feeding into the transmission
network - in 2009 a power reversal into
a 400 kV network occurred due to PV
generation, this now appears weekly in
2011(1
Aging and/or weak/ Complex grid
infrastructure:
E.g. in 2012, a scale power blackout
occurred in Northern/Eastern/North
Eastern India and, more than 650M
people were affected (2
Grid capacity:
Total worldwide installed generation
capacity will nearly double from 5324
GW in 2010 to 9669 GW in 2030 (3
Source: 1) LEW 2) Wikipedia 3) Energy Trends Study

10. © Siemens Ltd 2012
Transmission
Applications
Grid-specific
enterprise IT
Operational
IT
Information &
Communication
Automation
Field
equipment
Consulting, planning up to
implementation and installation
services
Blackout prevention through intelligent
simulation and monitoring software
Asset Management ISCM: Integrated
Substation Condition Monitoring based
on new and existing components
Minimization of life-cycle
costs and a long asset
lifetime can be achieved
through optimal
maintenance and avoidance
of overloads.
Smart Grid
Services
Business analytics, IT integration
Energy management system, network
stability and blackout prevention, grid
planning software
Backbone communication technology
power line carrier system
Substation automation with SICAM PAS
and SICAM 1703
RTU, protection devices,
power quality devices
Network consulting, asset management,
product-related services, performance
contracts
Integrated
solutions
Transmission Applications – current portfolio of
Siemens Smart Grids

11. © Siemens Ltd 2012
Distribution Applications

12. © Siemens Ltd 2012
Key challenges drive automation in distribution grids
Distributed energy
sources
Trends
Renewables
Aging and/or weak
infrastructure
Non-technical losses
Customer
challenges
Increasing distributed and/or
fluctuating generation:
E.g. share of world renewable
generation to triple from 4% to 13% in
2030 1)
Aging and/or weak grid
infrastructure:
E.g. in 2002, outages in distribution
grids affecting industrial, commercial
and residential customers cost the U.S.
over $79 billion in total 2)
Non-technical losses:
E.g. in India T&D losses (5%), in Brazil
(5.8%) due to non-technical causes,
e.g. electricity theft, cable theft3)
Source: 1) Energy Trends Study 2) U.S. 2002 CPI-weighted
dollars 3) Brazil Regulator, Energy Trends Study

13. © Siemens Ltd 2012
Distribution
Applications
Grid-specific
enterprise IT
Operational
IT
Information &
Communication
Automation
Field
equipment
Products – from field level to control
systems
Integration of SCADA and enterprise IT
(existing and build-up)
Systems are scalable and adaptable to
existing and future standards
Cost reduction of operations
on distribution level and
drop in outage times
through implementation of
integrated solutions – from
field level up to enterprise
IT.
Smart Grid
Services
Business analytics, IT integration
Distribution management system, grid
planning & simulation
Wireless & wireline communication
Distribution / feeder automation substation
automation
Protection devices, power quality devices,
distribution / feeder automation devices
Network consulting, asset management,
product-related services
Differentiation
Distribution Application – current portfolio of
Siemens Smart Grids

14. © Siemens Ltd 2012
Renewable Integration

15. © Siemens Ltd 2012
Key challenges drive renewable integration
Renewable generation
in distribution grids
Trends
Increasing electrical
loads in LV distribution
grids
Aging and/or weak
infrastructure
Customer
challenges
Overload of distribution grids due to
fluctuating renewable in-feed
E.g. share of world renewable
generation to triple from 4% to 13% in
2030 1)
High cost for integration of
renewable generation through grid
extension
Limited transparency on distribution
grid
Distribution grids are not designed
for bidirectional energy
Source: 1) Energy Trends Study 2) U.S. 2002 CPI-weighted
dollars 3) Brazil Regulator, Energy Trends Study

16. © Siemens Ltd 2012
Microgrid
Grid-specific
enterprise IT
Operational
IT
Information &
Communication
Automation
Field
equipment
Smart Grid diagnostics kit: consistent
and continuous measurement delivers
transparency in the distribution grid
overloads and power quality
Plug & play configuration: install the
package without difficult configurations
various communication solutions
secure VPN via GSM
Significant reduction of
investment cost required for
integration of renewables
and increase in efficiency of
distribution grid.
Smart Grid
Services
Business analytics, IT integration
Distribution management system
Smart Grid diagnostics kit
Support of standard communication
protocols (e.g. IEC 870-5-101/104)
RTUs for integration of power generation &
loads and for controllable LV transformer
Power quality devices, controllable LV
transformers, communication devices
Consulting for cost efficient grid extension,
installation, commission
Integrated
solutions
Renewable Integration – current portfolio of IC SG
Integration of distributed and renewable generation

17. © Siemens Ltd 2012
Demand Response/Virtual Power Plants

18. © Siemens Ltd 2012
Key challenges drive implementation of Demand
Response &
Virtual Power Plants
Generation & network
bottlenecks
Trends
Increasing peak load
prices
Increasing distributed &
renewable generation
Customer
challenges
Generation & network capacity
bottlenecks:
E.g. California, US
Increasing peak load prices:
E.g. Germany 6% in 2009
Dispatch load as most economic
power supply: Avoidance of
generation and network bottlenecks
and high peak load prices
Increased grid stability through
emergency load shed & selective
load dispatch
New market opportunities for
distributed energy resources
Rising consumption

19. © Siemens Ltd 2012
Virtual Power Plant
Grid-specific
enterprise IT
Operational
IT
Information &
Communication
Automation
Field
equipment
Business consulting for identification
and analysis of customer business
models
Energy management system for
monitoring, planning and optimized
operation of DER, loads and storage
Fully automated demand response
management system: DRMS platform
for load aggregation and enablement
Forecasting system for consumption
and renewable generation
Linking together a number of individual
plants to be combined to form a large-
scale virtual power plant
Optimized operation of decentralized
energy resources, load & storage,
enabling trading of energy flexibility
at minimized risk.
Smart Grid
Services
Business analytics, IT integration
Demand response management system (DRMS) ,
decentralized energy management system (DEMS)
Support of standard communication protocols like
IEC 104 and OPC, etc. over public/private TCP/IP
networks
Distributed energy resources (DER) controller
DER controller, load controller
Consulting, system installation & maintenance
site enrollment & enablement
Integrated solutions
Demand Response & Virtual Power Plant – current
portfolio of Siemens Smart Grids

20. © Siemens Ltd 201220
Wide Area monitoring
Power System Overview
Protection Systems
Grid Security & Stability
Table of contents
Feedback

21. © Siemens Ltd 2012
GSES System Structure and Tasks

22. © Siemens Ltd 2012
Framework for futuristic Transmission Protection

23. © Siemens Ltd 2012
DSA Procedure

24. © Siemens Ltd 2012

25. © Siemens Ltd 2012Page 25
Security Requirements for Smart Grid Applications
from a Variety of Potential Attacks (Examples)
Generation / DER
• Misuse of local
administrative rights
Distribution and Transmission
• Falsified status information, e.g., from synchrophasors (PMU)
in widely dispersed locations may limit the power flow.
Customer
• Prosumer behavior tracking,
e.g., through smart meters
• Fraud through smart meter
manipulation
Market
• Fraud based on falsified offers and
contracts (Customer, Utilities, DNOs, …)
Operation
• Unauthorized remote
service access

26. © Siemens Ltd 2012Page 26
Priorities in IT Security
Capacity problems today –
Cyber attacks tomorrow
Switch-Off is seen as one of the biggest risk in the context of
cyber security !
Availability / Protection – Integrity – Confidentiality
26th July 2012:
America preparedness
for a large scale cyber
attack is ‘3’ on a scale of
1 to 10

27. © Siemens Ltd 2012Page 27
Core Standards for Smart Grid
IEC TC57 Reference Architecture
Market Communication
IEC 62325
Common Information Model
IEC 61970 / 61968
Cyber Security
IEC 62351
Smart Metering
IEC 61334 DLMS, IEC 62056
COSEM
Substation Automation
Distribution Automation
DER Automation
IEC 61850
Tele-control Protocols
IEC 60870
DKE Roadmap
EU Mandate Report
IEC Roadmap
NIST Interop Report

28. © Siemens Ltd 2012Page 28
IEC 62351 produced by IEC TC57 WG15 –
Enables secure modern Energy Control Networks
 Integrity protection and encryption of control
data
 Part 1: Introduction
 Part 2: Glossary
 Part 3: Profiles including TCP/IP (cover those
profiles used by ICCP, IEC 60870-5 Part 104, DNP
3 over TCP/IP, and IEC 61850 over TCP/IP)
 Part 4: Profiles including MMS (cover those profiles
used by ICCP and IEC 61850)
 Part 5: Security for IEC 60870-5 and derivatives
(covers both serial and networked profiles)
 Part 6: Security for IEC 61850 Peer-to-Peer Profiles
(profiles that are not based on TCP/IP)
 Part 7: Network and System Management
 Part 8: Role Based Access Control
 Part 9: Key Management
 Part 10: Technical Report regarding Security
Architecture Guidelines for TC 57 Systems
 Part 11: Security for XML Files
Merging
Unit
Circuit
Breaker
Controller
CBC
Station Bus
Process Bus
Substation
Controller
Field
Devices
Control Center
IEC61850
IEC60870-5-101
IEC60870-5-104
DNP3
GOOSE
SVMMS

29. © Siemens Ltd 201229
Power System Overview
Grid Stability & Security
Protection Systems
Table of contents
Feedback
Wide Area Monitoring

30. © Siemens Ltd 201202.11.2012
Wide Area Monitoring
What is new?
Measurements via RTU / Substation
Automation
Synchrophasors via PMU
Update slowly (for example every 5 s) Continous update (measurement
stream) with for example 10 values
per second (= reporting rate)
No time correlation for measurements Every measurement has a timestamp
RMS values without phase angles Phasor values (Amplitude and phase
angle) for voltage and current
Dynamic View on Power Swings
and other dynamic phenomena

31. © Siemens Ltd 201202.11.2012
PMU
Calculation of “Total Vector Error”
Amplituden- und Phasenwinkelfehler
müssen beide für die Synchrozeiger-
genauigkeit betrachtet werden.
Both amplitude and phase angle error
have to be considered for
synchrophasor accuracy.

32. © Siemens Ltd 201202.11.2012
Structure of a Wide Area Monitoring System
User Interface 1 User Interface 2
PMU1 PMU2 PMU n
IEEE C37.118
PDC 1
PDC 2
ICCP
to Control Center
Region 1 Region 2
PMU : Phasor Measurement Unit
PDC: Phasor Data Concentrator

33. © Siemens Ltd 201202.11.2012
SIGUARD Phasor Data Processing System
Application
SIMEAS R-PMU
TPR / CPR
SICAM
PQS
Offline-Analyzing
Measurements
Online/Offline
Analyzing
IEEE
C37.118
SIGUARD
PDP

34. © Siemens Ltd 201202.11.2012
Userinterface
Power System Status Curve
Monitoring of
- Online view or
- Historic view (selectable)
Phasor diagrams
Time charts
Geographical View (Google Earth based)
Event List

35. © Siemens Ltd 201235
Power System Overview
Grid Stability & Security
Wide Area Monitoring
Table of contents
Feedback
Protection Systems

36. © Siemens Ltd 2012
Protective Relaying is the most important
feature of power system design aimed at
minimising the damage to equipment and
interruption to service in the event of faults. It
is therefore a co-factor among other factors
resorted to improve reliability of power system.
Protective Relaying
Role of Protection

37. © Siemens Ltd 2012
The Purpose of Protection
But it can:
Limit the damage caused by short
circuits
While:
Protecting people and plant from
damage
Selectively clearing faults in
miliseconds
Protecting plant from overload
conditions
The protection can not prevent system faults,
Power system must operate in a safe manner at all times.

38. © Siemens Ltd 2012
Causes and Probability of System Disturbances
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39. © Siemens Ltd 2012
Since protective relaying comes into action at the time of
equipment distress, a certain safeguard is necessary in
the unlikely event of its failure to act at the hour of need.
Hence, two groups of protective schemes are generally
employed -
a) Primary Protection
b) Back-up Protection
Primary Protection is the first line of defense, whereas
back-up relaying takes over the protection of equipment,
should the primary protection fail.
Principles of Relaying

40. © Siemens Ltd 2012
The Primary Protection has following characteristic
features -
1. It has always a defined zone of operation.
2. It should operate before any back-up protection
could operate, therefore, it should be faster in
operation.
3. It should be able to completely isolate the fault
from all the current feeding sources.
4. It should be stable for all operating conditions.
Primary Protection

41. © Siemens Ltd 2012
1. Back-up protection should provide sufficient time
for the primary protection to perform its duty.
2. Back-up protection covers a wider zone of
protection. Therefore, there is always a possibility
of large scale disturbance, when back-up relays
operate.
3. Under primary protection failure, several back-up
relays may operate for complete isolation of fault.
Back-up Protection

42. © Siemens Ltd 2012
Primary protections failure could be due to any of the
following reasons -
1. Current or Potential Transformer failure
2. Loss of Auxiliary Control Voltage
3. Defective Primary Relays
4. Open Circuits in Control & Trip Coil
5. Failure of Breaker
It is therefore logical that back-up relays should not
utilise any of the above items as common with primary
relays.
Reasons of Primary Protection Failure

43. © Siemens Ltd 2012
Protection Concept
 The system is only as strong as the weakest link!
DISTANCE RELAY
Cabling

44. © Siemens Ltd 2012
Basic Protection Requirements
 Reliability dependability (availability)
high dependability = low risk of failure to trip
 Security stable for all operating conditions ,
high security = low risk of over-trip
 Speed high speed minimizes damage
high speed reduces stability problems
 Selectivity trip the minimum number of circuit breakers
 Sensitivity notice smallest fault value

45. © Siemens Ltd 2012
Evolution
First use of
electromagnetic
relays
First digital
application in
Würzburg,
Germany
The digital age
begins for relays
Introduction of
the SIPROTEC
4 product group
Siemens is
honored by Frost
& Sullivan for the
implementation of
IEC 61850
SIPROTEC
Compact –
outstanding
functionality and
compact design
More than one
million
SIPROTEC-
devices in
operation
SIPROTEC 5
The new
benchmark for
protection,
automation and
monitoring

46. © Siemens Ltd 2012
Equipment
Signal
conversion
Signal
tailoring
Processing
(calculation)
Signal
analysis
Tripping
signal
Tripping
coil
Circuit
breaker
Protection device
Auxiliary supply Settings AnnunciationBinary Inputs
General Structure of a Numerical Protection Device

47. © Siemens Ltd 2012
Functional Integration

48. © Siemens Ltd 2012
Functional Protections
Breaker
management
Line differential
protection
Overcurrent and
feeder protection
Bay controller
Combined line
differential and distance
protection
Distance protection
Transformer
differential
protection
Fault Recorder

49. © Siemens Ltd 2012
Scenario for a decentralized Feeder Automation
solution approach with 7SC80
Substation B
DMS
Backhaul
to Control
Center
CB Substation A
Recloser
Load Switch
Transformer
IEC 61850
Communication
Network, e.g. .
WIMAX, Wi-Fi i
NOP

50. © Siemens Ltd 2012
Ethernet and IEC 61850
The Initial Situation
 Devices communicate with one
another through wiring.
 Slow serial communications
protocols are used (master-slave
technique).
 Within a switchgear system,
diverse, in part proprietary
communications protocols are
used.
 Frequently, a cost-intensive data
conversion is necessary.
 Redundancy can only be
achieved by doubling the
communication (two busses).
Network Control Level
Station Level
Field Level
Process Level
100V..120V, 1A/5A Hardwired
Hardwired
binary inputs and outputs
IEC 60870-5-101, DNP, ...
IEC 60870-5-101 / 103, DNP, ...

51. © Siemens Ltd 2012
Ethernet and IEC 61850
The Solution
 Currently, an integrated
communication without protocol
conversion is possible up to the
Station Level.
 Siemens masters and
implements communication up to
the Network Control Level and
brings this experience into the
continuous standardization.
 IEC 61850 uses the standard
Ethernet.
 The standard supplies thought-
out migration concepts, even for
heterogeneous systems.
 The data model is future-
oriented, independent of
innovation advancements.
Network Control Level
Station Level
Field Level
Process Level
IEC61850
IEC61850solutions
fromSiemens

52. © Siemens Ltd 2012
IEC 61850 communication within a substation
Control Center
IEC 608705-104
DNP3 TCP
Digital Instrument
Transformer
Data via IEC61850-9-2
CT
VT
xCircuit
Breaker
Controller
1
2
3rd
party
device
Parallel wiring
Substation Controller
Process bus
3
Station bus
Control / Inforeport
(ca. 500 ms delay time)
1
2
GOOSE Inter IED Communication
(ca. 10-100 ms, dep. on application)
3
Sampled Values
(ca 2 ms delay time)
Merging
Unit

53. © Siemens Ltd 2012
IEC 61850 – Future of the Communication of the
Energy Automation Systems
Conventional and
unconventional CT / VT
Netzleitstelle
Device Device
Router
Firewall
Merging
Unit
IEC 61850 Station bus
Process bus (sampled measured values IEC 61850 9-2)
Communication
with CC
CIM IEC 61970
IEC61850 Communication
between
Substations
Data Security
IEC 62351- 6
IEC 61850
Edition 2
and Application for
Hydro and Wind
Power, and
DistributedEnergy
Resources
Network redundancy
and
time synchronization
acc. IEEE 1588

54. © Siemens Ltd 2012
Ethernet and IEC 61850
We Think Beyond
IEC 61850 and Ethernet
Protection & Control
Digital Converter
Data Transmission according to IEC 61850-9-2
*Standardization in work
Network Control Centre
Device Device
Router
Firewall
Gateway
Merging
Unit
CB
Control Unit
IEC 61850 Station Bus
IEC 61850 Process Bus
Harmonization
with CIM
IEC 61970* Communication
with other Switch-
gear Systems*
Process Control
System

55. © Siemens Ltd 201256
Power System Overview
Grid Stability & Security
Wide Area Monitoring
Table of contents
Protection Systems
Feedback

56. © Siemens Ltd 2012
Shaping tomorrow’s power networks
Thank You!
vikram.gandotra@siemens.com