Scada Siemens
Short Description
Download Scada Siemens...
Description
Distribution Network Automation & Control
Seminar Jan 29/30, 2008 Tehran/Iran
Dr. Roland Eichler ©
Siemens AG 2008
Seminar
Strategies for distribution automation Control in substations and outstations Communication Process optimization in the Control Center and customer related activities Control Center
Substation
Substation
Outstation
Outstation Outstation
Substation
Outstation
Outstation
Outstation Outstation
Outstation
Outstation ©
Page 3
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (I)
Tuesday, Jan 29, 2008 Section 1: Goal, task and aspects of distribution automation Section 2: Impacts on planning of distribution automation Section 3: Selection of substations to work under automation – automation layout Section 4: Which parameters should be measured or controlled ? Section 5: Selection criteria for hardware, software and communications Section 6: Distribution automation standards
©
Page 4
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (II)
Wednesday, Jan 30, 2008 Section 7: SCADA functionalities Section 8: DMS functionalities Section 9: Case study presentation Section 10: Distribution system automation personnel skills Section 11: Maintenance and support procedures
©
Page 5
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (I)
Tuesday, Jan 29, 2008 Section 1: Goal, task and aspects of distribution automation Section 2: Impacts on planning of distribution automation Section 3: Selection of substations to work under automation – automation layout Section 4: Which parameters should be measured or controlled ? Section 5: Selection criteria for hardware, software and communications Section 6: Distribution automation standards
©
Page 6
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Mission of the Electricity Supply System
The primary aim of an electricity supply system is to meet the customer’s demands for energy (in sufficient quantity and quality, at the required time and at an acceptable price)
Similarity to other goods consumption processes, the Electricity Business comprises 4 basics components
Demand
Production (Generation)
(Sub-)Transmission
Distribution ©
Page 7
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Requirements to the Distribution System
Supplier’s View
Customer’s View
high
efficiency with low losses few assets easy service less maintenance fast fault detection
high
availability no faults high power quality low price quick recovery
©
Page 8
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Customer Requirements and Supply Standards Availability no interrupts i.e. continuity of supply Power Quality Voltage Frequency Harmonics Transients Definitions of supply reliability are quite different therefore statistic values can not be compared exactly most countries count outages longer than 3 minutes, some define a 1 minute limit (Great Britain, Portugal) Continuity indicators are calculated in a different way Weighted by the number of customer Weighted by the power affected (Spain, Portugal) Some consider Acts of God, some don’t ©
Page 9
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Power Quality Standards Voltage in Europe According IEC 61000 Voltage in the USA : the American National Standard Institute (ANSI) defines "Voltage Range " as: 120/240V ±5% at the user's service entrance, and 120/240V ±8,33% at the point of utilisation. Frequency The vast majority of equipment appliances are not much sensitive to variation of frequency. Furthermore, in interconnected networks (e.g. UCPTE,..) the frequency (50 Hz or 60 Hz) is generally very stable and secondly source of problems. Quality According IEC 61000 ©
Page 10
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Power Interrupt Statistic in Europe Length of power interrupts in minutes per year (1999) in some countries 400 364
350 300
Power-weighted indicators
Time [min]
Customer-weighted indicators 250 200
180
191 157
152
150 100 50 15
57
63
FRA
GBR
25
0 GER
NLD
SWE
Country
NOR
ITA
SPA
POR
Source: Council of European Energy Regulators CEER 2001 ©
Page 11
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Social Cost for Unplanned Outage Customer’s Cost for an Unexpected Outage [ $ per Interrupted kW ]
Swedish nationwide survey for unexpected outages, 1993
7
$ 6
5
de a Tr
&
+ 95 1.
$
W /k
es c i rv e S
Sm
y str u Ind l l a
ustry d n I e Larg
4
3
2
60 9.
h W k /
lture u c i r Ag
5 / kW 7 . 0 $
$
kW / 5 1.3
0 $ 2.7
/ kW
+$
/ kW 5 5.2
h
/ kWh 0 0 . +$3
h 0 / kW 5 . 2 +$
1
Domestic 20 Page 12
Jan 2008
Dr. Roland Eichler
Outage’s Duration
$ 0.15 / kW + $ 0.30 / kWh 40
[ Minutes Siemens AG 2008] Power Transmission and Distribution ©
Energy not Supplied due to Fault Outages
Transmission 33 - 420 kV 27%
Distribution 1-22 kV Transmission 33 - 420 kV
Distribution 1-22 kV 73%
Source: Cigré Conference, Paris, 2002 ©
Page 13
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Why to Improve the Distribution System
The transmission and the sub-transmission system have already high reliability Therefore: Distribution Automation has the best ratio Improvement to Invest Strategies to optimize the distribution system n-1 strategies are very expensive structure of the system can not be changed easily But even with rather cheap measures one can reduce the outage times dramatically
©
Page 14
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Breakdown of Capital Expenditure Reliability vs Investment Cost
10kV Overhead Line 10% 5% 10%
Maintenance Commissioning Erection
25%
Assembly
10%
Design
Reliability [Rel]
1.0 ∆C2
0.8 0.6 ∆Rel1
Diminishing Returns ∆C1 = ∆C2 ∆Rel1 >> ∆Rel2
0.4 ∆C1 0.2
40%
∆Rel2
Equipment
0 Investment [C]
©
Page 15
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Supply Quality vs. Cost: A Macro Economic Consideration
Costs
Macro Economic Costs Limits (Law, Standards)
Cost for Invest and Maintenance Cost for Interrupts (Less Sold, Penalties)
Supply Quality ©
Page 16
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
What is ‘Distribution Automation’ There is no fixed definition of the term. Definition from EPRI 2004: The objective of (Advanced) Distribution Automation Function is to enhance the reliability of power system service, power quality, and power system efficiency, by automating the following three processes of distribution operation control: data preparation in near-real-time; optimal decision-making; and the control of distribution operations in coordination with transmission and generation systems (Note: Distributed Energy Resources !) operations Others (e.g. CIRED AD HOC Working Group 2 ) add topics such as ‚establish closer and more responsive relationship with customers‘. ©
Page 17
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Utilities’ view on ‘Distribution Automation’ “ Improved automated workflow of the Operation and Planning Department ” ( North York Hydro ) “ Improved supply quality and minimising of not sold kWh “ (CIRED 1987) “ Improved efficiency and quality of service, more rational use of energy “ (ENEL)
©
Page 18
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Automation Main Function Sets Network Operation
Operational Planning, Optimization
Customer Interface, Management & Control
Maintenance Management
Data Management
Network Operation Monitoring
Network Operation Simulation
Loads and Meters Readings Control
Operation Feedback Analysis
Technical Data Management
Network Control
Switching Actions Scheduling
Customer Trouble Information
Maintenance Works Scheduling and Control
Dynamic Data Management
Fault Management
Power Import Scheduling and Optimization
Billing & Settlement
Operation Statistics and Reporting
Management Information System
Geographical Displays Source: CIRED Ad Hoc Working Group 2 ©
Page 19
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Benefits in Network Operation (I) Improving the quality of service Data acquisition, monitoring and remote control also at remote sites allows responding to alert and emergency conditions quickly and confidently and with the correct action, e.g. low voltage unbalanced flows low power factor overload Less and shorter outages lead to increased revenue Better network supervision means less equipment failure Equipment lifetime is lengthened Cost for maintenance material and manpower is reduced
©
Page 20
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Benefits in Network Operation (II)
Increased safety and security Operation of any electrically controllable device can be securely inhibited at the SCADA master station Remote outstations can be monitored for intrusion Reduction of staff in remote outstations Power Quality Calculations (Power Auditing) the open market imposes penalties for quality of service not compliant with minimum characteristics. Energy and Power Balances some utilities have high amount of energy losses. The first step for correcting this problem is to determine where losses larger than normal are located, this includes both technical and non-technical losses ©
Page 21
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Benefits in Network Operation (III) Improve Quality of Service SPM: Operator always has a clear picture about the current status and further planned steps of each switching sequence – faster switching at lower risk Floc / FISR: Shorten interruption time by automatically identifying candidate switching actions for isolation of faults restoration of supply switching back to normal DSPF: Detection of Limit Violations that would occur after planned switching actions – avoiding overloads and accidental customer supply interruptions Improve Efficiency of Network Operation VVC/OFR: Keep the system at the minimum of technical losses thus reducing cost Fichtner Fichtner Consulting Consulting estimates estimates reduction reduction of of losses losses gained gained from from optimized optimized network network operation operation using using applications applications such such as as OFR OFR and and VVC © Siemens AG 2008 VVC to to 0.4% 0.4% –– 0.5% 0.5% of of the the electrical electrical energy energy delivered. delivered. Page 22
Jan 2008
Dr. Roland Eichler
Power Transmission and Distribution
Distribution Automation Main Function Sets Network Operation
Operational Planning, Optimization
Customer Interface, Management & Control
Maintenance Management
Data Management
Network Operation Monitoring
Network Operation Simulation
Loads and Meters Readings Control
Operation Feedback Analysis
Technical Data Management
Network Control
Switching Actions Scheduling
Customer Trouble Information
Maintenance Works Scheduling and Control
Dynamic Data Management
Fault Management
Power Import Scheduling and Optimization
Billing & Settlement
Operation Statistics and Reporting
Management Information System
Geographical Displays Source: CIRED Ad Hoc Working Group 2 ©
Page 23
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Benefits from Automatic Meter Reading (AMR) Systems
identification Æ Loss reduction Æ Revenue enhancement Operational Efficiency and Asset Utilization Monitor energy balance & peak demand reduction Faster response time to customers Earn from innovative services to consumers e.g. Loss
Load
profile via web access Security services e.g. door control
By
using the AMR infrastructure Power
Quality system on top ©
Page 24
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Automation Main Function Sets Network Operation
Operational Planning, Optimization
Customer Interface, Management & Control
Maintenance Management
Data Management
Network Operation Monitoring
Network Operation Simulation
Loads and Meters Readings Control
Operation Feedback Analysis
Technical Data Management
Network Control
Switching Actions Scheduling
Customer Trouble Information
Maintenance Works Scheduling and Control
Dynamic Data Management
Fault Management
Power Import Scheduling and Optimization
Billing & Settlement
Operation Statistics and Reporting
Management Information System
Geographical Displays Source: CIRED Ad Hoc Working Group 2 ©
Page 25
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Benefits from Real Time Energy Management System (RTEMS)
Integration
of meter-to-bill processes and systems ¾ Improve cash flow, and system reliability
Consolidation
of customer data and meter data repositories ¾ Improve trust and reduce cost
Allowing
web-based display and usage of energy demand and consumption information at the consumer‘s site ¾ Reduce cost, improve customer retention / satisfaction and quality
Enabling
real time monitoring of power quality information and automated response to energy distribution events
Sell
power quality services and increase margin ©
Page 26
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Automation Main Function Sets Network Operation
Operational Planning, Optimization
Customer Interface, Management & Control
Maintenance Management
Data Management
Network Operation Monitoring
Network Operation Simulation
Loads and Meters Readings Control
Operation Feedback Analysis
Technical Data Management
Network Control
Switching Actions Scheduling
Customer Trouble Information
Maintenance Works Scheduling and Control
Dynamic Data Management
Fault Management
Power Import Scheduling and Optimization
Billing & Settlement
Operation Statistics and Reporting
Management Information System
Geographical Displays Source: CIRED Ad Hoc Working Group 2 ©
Page 27
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Benefits from Management Information System Obtain more information from the network for a safer, more reliable and more efficient operation extremely useful for cost efficient network planning because information on real equipment loading avoids over-sizing e.g. for installed transformer capacity planning of just-in-time maintenance based on actual equipment stress generation of logs and reports for after-the-fact system analysis and management information; everybody can create the reports he/she needs (no software or database knowledge required, only brief handling training) Precise, on-time, and comprehensive information increases management awareness of actual situation and increases efficiency of department cooperation A distribution utility has reported a 100,000 US$/per year saving because new distribution substations could be better planned - at the right time at the right place.
Calculation of Quality of Service Indices for individual distribution points – clear proof of power supply quality ©
Page 28
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Automation Some more potential achievements Minimization of non-in-time delivered energy reduce by 20% the current values (conservative figure) Network losses minimization reduce by 5% the current values (conservative figure) Improved Operation efficiency 10% of the Operation’s budget Improved Image equivalent or better market penetration with reduced marketing costs Improved working conditions and environment stable personnel, less recruitment costs (and related training) ©
Page 29
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (I)
Tuesday, Jan 29, 2008 Section 1: Goal, task and aspects of distribution automation Section 2: Impacts on planning of distribution automation Section 3: Selection of substations to work under automation – automation layout Section 4: Which parameters should be measured or controlled ? Section 5: Selection criteria for hardware, software and communications Section 6: Distribution automation standards
©
Page 30
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Impacts on planning of distribution automation (I) The general benefits from distribution automation have been clarified in Section 1. This has answered the WHY of distribution automation. The utility‘s priority of goals defines WHAT shall be done i.e. what is more important to achieve: increasing supply reliability increasing power quality decreasing cost decreasing loss of revenue etc
This priority list will guide the selection of the most suitable program for distribution automation i.e. what will be done first. ©
Page 31
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Impacts on planning of distribution automation (II) After the utility has answered the strategic WHAT question the next question is HOW the distribution automation solution shall be implemented i.e. what are technical / environmental / legal / … constraints. This concerns issues such as: overhead vs. underground networks availability of communication technology available (inter-)national standards already existing automation / communication infrastructure accessibility of substations current and future importance of substations etc
©
Page 32
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Impacts on planning of distribution automation (III) Normally there will be several proposals for achieving the ‘WHAT goals’ considering the ‘HOW constraints’. Besides the achievement of the strategic WHAT criteria there are general criteria for selecting the most suitable distribution automation proposal: flexibility of the distribution automation solution in case of changing
strategic goals of the utility flexibility for adding more services/business in the future expandability of the distribution automation solution in case of growing system size e.g. due to mergers with other utilities reliability of the distribution automation solution itself investment cost & cost for operation and maintenance of the distribution automation solution vs. monetary achievements ©
Page 33
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Components of a distribution automation solution (I) A properly selected distribution automation solution will comprise answers to the following questions: Which substations should be automated to what extent ? ¾Remote metering/monitoring ¾Remote switch control Which data shall be collected from which substation ? Which control centers shall be built/used (centralized/distributed) ? Which redundancy concepts shall be implemented ? Which communication media shall be built/used for which type of
link? Which communication configuration shall be built (point-to-point, network, radial, ...) ? ©
Page 34
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Components of a distribution automation solution (II)
Which software packages are required ? Which interfaces are required ? ¾to external control centers ¾to external applications, such as GIS, CRM, etc Which metering, accounting, settlement and billing process shall be
applied ? Which standards shall be used ?
©
Page 35
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Components of a distribution automation solution (III)
What is the capital expenditure for such a system ? Which achievements are expected with regard to the strategic WHAT
goals ? ¾reduction of outage frequency ¾reduction of outage duration ¾cost reduction ¾etc How can such a system be implemented and maintained ? How can databases be populated and maintained ? How can the implementation be split in several phases for early
benefit achieving ? Which training is needed at what time for operational staff and administration ? ©
Page 36
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Anticipated Problems with Distribution Automation #1: Centralized Control System Apprehension: „Due to the automation of distribution networks the number of data points and RTU lines to be processed increases dramatically and thus exceeds the processing capabilities of centralized systems“ large amount of data is not any more limiting the processing
capabilities of modern SCADA/DMS modern process interfaces can handle hundreds of RTU lines, furthermore there are possibilities for ¾running several RTU servers in parallel ¾‚lean‘ RTU interfacing by means of TCP/IP based protocols ¾use of modem pools ¾cascading of RTUs, i.e. small field RTUs talk ‚through‘ large substation RTUs ©
Page 37
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Anticipated Problems with Distribution Automation #2: Communication
Apprehension: „The automation of distribution networks fails due to insufficient communication lines.” cascading of RTUs reduces the number of communication lines
needed alternative communication media are available power line carrier over distribution lines mobile phone networks such as GSM, GPRS dial-up lines over public phone companies
©
Page 38
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Anticipated Problems with Distribution Automation #3: Cost
Apprehension: „The automation of the entire distribution network is too expensive.” in the course of energy market liberalization the pressure for cost
reduction from regulation authorities on distribution companies will constantly grow and justify ever more investment in distribution automation cost for energy automation equipment and communication
equipment is decreasing particularly for compact RTUs and dial-up connections via mobile telephone systems distribution automation does not come as ‚big bang‘; it rather grows
over time closely coordinated with investment / maintenance programs for substations ©
Page 39
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (I)
Tuesday, Jan 29, 2008 Section 1: Goal, task and aspects of distribution automation Section 2: Impacts on planning of distribution automation Section 3: Selection of substations to work under automation –
automation layout Section 4: Which parameters should be measured or controlled ? Section 5: Selection criteria for hardware, software and communications Section 6: Distribution automation standards
©
Page 40
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
The Last Meters: Low Voltage 115 V /125 V Systems Mainly used in USA, Canada, Brasilia, Mexico, Saudi Arabia, Korea, Philippines typical 60 Hz and requires transformer nearby the consumer main distribution to the end consumer is done by the MV grid 230 V / 400 V Systems Mainly used in Europe typical 50 Hz Ohmic power losses enable distance up to 2 km to the next MV / LV transformer main distribution to the end consumer is done by the LV grid ©
Page 41
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Structure of the Power System in USA 115 V Transmission National / International
Subtransmission Regional
Distribution System
Low Voltage ©
Page 42
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Structure of the Power System in Europe 230 / 400 V Transmission National / International
Subtransmission Regional
Distribution System
Low Voltage ©
Page 43
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Typical sub-transmission/distribution configuration
220KV/33KV Rec. Stn
X X
X
X X
X
X
220KV
X X 33KV
33KV/11KV Rec. Stn.
Scope of this seminar 11KV
Compact Distribution Station – Ring Main Units
©
Page 44
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Urban underground MV networks Circuit breaker
20/0,4kV C
D Load-breaking switch
A c 110/20kV
d S
B
Fuse
20/0,4kV S
Isolation point
At a suitable point on the network the loop is opened by a sectionalising device S. This may be a circuit breaker, switch, fuse or link. The system then effectively operates as two radial feeders. © Siemens AG 2008 Page 45
Jan 2008
Dr. Roland Eichler
Power Transmission and Distribution
Overhead rural MV networks The figure shows schematically typical arrangements for a rural overhead radial feeder, with some of the manually operated disconnectors omitted for simplicity. It will be noted that each main trunk feeder has a number of lateral spurs.
©
Page 46
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Substation type #1 with permanent data access Substations of type 1 establish permanent communication between the control centre and the distribution substation e.g. by means of optical fibres. Often the fibres of a secondary communication network are interconnected with a node (receiving station) of the primary fibre optic ring. Applications such as RTU and AMR use TCP/IP. IEC 60870-5-104 is recommended for RTU communication. Of course, other communication media / protocols are possible. Page 47
Jan 2008
FO from R/S, S/S
FO to next S/S
Fibre panel 1 (2) *24 Fibre optic to UTP Media Converters 8 port Ethernet HUB
RTU (IEC…104)
Meter
Control & Monitor switch states, Short circuit indicators
motorized 11kV Switchgear
CT, VT
Battery charger Battery 24/48V DC
Sample configuration
©
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Substation type #2 with temporary data access Substations of type 2 use switched telephone communication facilities (fixed wired or mobile communication) to transfer data on demand. The demand for data exchange can be initiated by the control centre or the distribution substation itself. The control centre needs to control switchgears remotely, to ask for data update or just to test the connection. The substation need to call in the control centre if there is some urgent data to transfer, for example a fault indication on a 11kV incoming or outgoing line. Page 48
Jan 2008
Dial up Modem (WLL/Fixed wired)
RTU (IEC…101)
Control & Monitor switch states, Short circuit indicators
motorized 11kV Switchgear Energy Meter
CT, VT
Battery charger 24/48 V DC
Battery 24/48V DC
Sample configuration
©
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Steps of Distribution Automation Step 0: Centralization of distribution system operation
centralized distribution system operation is less costly centralized distribution system operation reduces time to restore
supply after disturbances existing mixed structures of local and centralized operation often
have grown over time but do not have justification as of today mixed structures in case of disturbances, i.e. local operation only
temporarily, are questionable in terms of organization reliability
©
Page 49
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Steps of Distribution Automation Step 1a: Automation of feeder heads in HV/MV substations in
case of a new HV/MV substation the whole scope of automation shall be built in: remote
signaling of all switching element statuses remote control of circuit breakers digital protection devices provide analog measurements in normal operation and fault operation in
case of retrofitting HV/MV substations the following priority applies must: optional: nice-to-have:
fault information from protection equipment per field remote control of circuit breakers analog measurements of feeder currents more switching status information (isolator, earthing switch, ...) ©
Page 50
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Steps of Distribution Automation Step 1b: Automation of major switching substations
Major switching substation: three (3) outgoing feeders or more circuit breaker and protection In case of a new switching substation the whole scope of automation shall be built in (see Step 1a) In case of retrofitting switching substations the same priorities apply as in Step 1a.
©
Page 51
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Steps of Distribution Automation Step 1c: Remote signaling of selected fault current sensors
With this step the utility has reached the level of automated centralized fault location: evaluation of topology information evaluation of fault impedances evaluation of fault current sensor information consideration of additional information received via phone
©
Page 52
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Steps of Distribution Automation Step 2a: Automation of selected MV/LV substations
Selected MV/LV substations: ‘normally open’ section point midway of long feeders
Remote control of load switches This normally implies the necessity to motorize the switches.
©
Page 53
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Steps of Distribution Automation Step 2b: Automation of selected customer substations
Selected customer substations: high-volume consumer high-sensitive consumer
remote signaling of fault information remote switching remote signaling of analog measurements
This enables new business opportunities for providing high-quality power supply services to those customers. ©
Page 54
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Selection of distribution substations for automation For the selection of distribution substations for automation two main questions have to be answered: (A) What is the most reasonable and beneficial
rate of automation for distribution substations? (B) Which dedicated distribution substations shall be automated ? The goal of distribution substation automation is basically to reduce the average interruption time of energy supply in the distribution network. In case of a feeder trip the SCADA/DMS operators get fault indication from automated distribution substations. Within a short time a part of the affected consumers can be re-supplied by reconfiguring the distribution network by remote control actions from the SCADA/DMS. DMS applications will support the operator in defining the most appropriate switching sequence (Section 8). ©
Page 55
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Selection of distribution substations for automation Question (A): Automation Rate (I) A fault on a cable section causes the feeder to trip. Two distribution substations will send fault indications and faultdirection to the control centre. Based on this information the operator can re-supply ~ 50% of the affected consumers by performing switching actions 2 - 5. This can be done within a time period of 3 minutes.
Automation rate assumed to be 25%. R/S feeder
R/S feeder 650 feeders 4099 distribution substations D6,5 substations / feeder
1. trip 3. close
2,2 million consumers D537 consumers / substation
Normally open point 2. open
5. close
4. open
Fault indicator Automated substation
About 50% of the affected customers re-supplied after 3 minutes. ©
Page 56
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Selection of distribution substations for automation Question (A): Automation Rate (II) Compared to nonautomation, the restoration crew can work faster since the area of intervention is only a part of the feeder. Fault isolation and service restoration are done by conventional methods. The crew on site can be supported by the operators in the control centre. Average conventional restoration time is estimated to be reduced by 50 % (40 minutes Î 20 minutes).
Automation rate assumed to be 25%. R/S feeder
R/S feeder
Fault indicator Automated substation
Remaining 50% of the affected customers re-supplied after 20 minutes. ©
Page 57
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Selection of distribution substations for automation Question (A): Automation Rate (III) As result of this scenario the service restoration time will be reduced from approximately 40 minutes to approximately 11 Minutes. 50 % of consumers are re-supplied after 50 % of consumers are re-supplied after => average interruption time
3 minutes 20 minutes ~11 minutes
This kind of estimation of outage time reduction can be repeated for other values of the automation rate. The diagram on the next page indicates the average interruption time as function of the number of automated substations (magenta) taken from a study case. Relevant study case data are given on the following page. The blue curve is representing the Net Present Value (cost/benefit ratio). The costs are based on the substation adaptation investments, the benefits are calculated from more energy sold due to reduced average interruption time.
©
Page 58
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Selection of distribution substations for automation Question (A): Automation Rate (IV)
Detailed Case Study on Cost-Benefit-
Analysis of Distribution Automation with different Automation Rates in Section 9.
©
Page 59
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Selection of distribution substations for automation (VI) Question (B): Selection of Substations The selection of dedicated substations for automation does not follow a strict and simple algorithm. It is rather guided by fuzzy criteria on two levels: Feeder level Such feeders will be preferred that have ¾ higher load density ¾ higher fault density than others Substation level Obviously the substation with ‚normal open points‘ will be automated first on a selected feeder. As regards other substations, the leading criterion is the load that can be affected i.e. those substations will be preferred that have ¾ large industrial consumers connected ¾ spur lines with high load connected Finally, the time needed for manual switching plays a role i.e. those substations will be preferred that have ¾ long travel time to reach ©
Page 60
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (I)
Tuesday, Jan 29, 2008 Section 1: Goal, task and aspects of distribution automation Section 2: Impacts on planning of distribution automation Section 3: Selection of substations to work under automation – automation layout Section 4: Which parameters should be measured or controlled ? Section 5: Selection criteria for hardware, software and communications Section 6: Distribution automation standards
©
Page 61
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Data to be collected from HV/MV Substations Active Power, Reactive Power, Voltages, Currents from all ¾incoming feeders ¾outgoing feeders ¾capacitor banks ¾etc Switch Positions of the ¾Isolators (Single Pole) ¾Circuit Breakers (Double Pole) Indications of other auxiliary devices such as UPS, Battery
system, Chargers, Communication Devices etc. Status from the protection devices Transformer tap position
©
Page 62
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Data to be collected from Distribution S/S Input to SCADA
Output from SCADA
Circuit breakers
Status
Command
Load switches
Status
(Command)
Switches
Analogs I/P/Q/V
Measured Value
Protection (each feeder) Phase-to-phase short circuit
Alarm
Phase-to-ground short circuit
Alarm
Fault current sensors
Alarm
Battery System
Page 63
Power supply failure
Alarm
Charger failure
Alarm
Charge low
Alarm
Jan 2008
Dr. Roland Eichler
©
Siemens AG 2008 Power Transmission and Distribution
Data to be collected for distribution automation Bulk supply Substation
Step 2:
220 kV bus
Line/cable segment engineering data
Step 1: Extended SCADA Data Model
33 kV bus
Step 3: Measurements from distribution automation
Typical load curves for load transformers
Receiving Substation 33 kV bus
Step Step 0: 0:
M
SCADA SCADA data data model model
M M M
11 kV bus M
M
M
M
1. Extend by SCADA data model of distribution feeders (topology, switches) Î enabling Operation Applications (Section 8) 2. Extend by engineering data of line/cable segments and load models Î enabling Distribution Network Applications (Section 8) 3. Add measurements from automated distribution substations; substitute load models ©
Page 64
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Short-circuits and earth-faults indicators
criterion Is1 and dt fullfilled -> indication is activated
I> (t)
selected pick-up current
IS1
enveloping of failure current
Integrative measurement avoids erroneous indication! Red signal curves must not activate the indicator
dt
t
pick-up time dt selectable: 40 oder 80 ms
For effective failure detection and location short-circuits and earth-faults must be observed. Combined shortcircuit and earth-fault indicators are most economical. Indicators can be installed on outgoing feeders of RMUs. The fault detection facility generates alarms in case of high current peaks. However, the facility shall prevent faulty indications due to magnetizinginrush currents, other transient and nofault conditions.
©
Page 65
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Fault detection in low resistance terminated networks by means of short-circuit indicators
Umspannwerk Power substation
Knotenpunktstation nodal point substation RMU
I>> Ie RMU
I>> Ie
RMU
I>> Ie
RMU
I>> Ie
I>> Ie
RMU
I>> Ie
RMU
I>> Ie
RMU
I>> Ie
I>> Ie
©
Page 66
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Typical Repairing of Permanent Faults
Protection has tripped circuit breaker CB Transient fault? Automatic recovery? Localize fault ¾phone calls, relay data, Remote Terminal Units (RTU),
visually Open isolator and ground equipment Restore supply as much as possible Do nessesary repair work Fault removed, line repaired Remove grounding and close isolator or replace fuse Switch back to normal state
©
Page 67
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Urban vs. Rural Regions
Urban underground cables with less external faults
Rural a lot of overhead lines intermediate short circuits birds trees wind Auto recloser strategies
©
Page 68
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Automation in Urban Areas Example for Ring Main Automation ©
Page 69
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Typical open ring configuration
OC
OC
FI OC: over current protection FI: fault indicator
©
Page 70
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Outstation (Ring Main Station, Satellite Station)
©
Page 71
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Typical mini RTU solutions Double indications:
Ring main unit with one feeder
Ring unit 1 isolator Earth switch 1 Ring unit 2 isolator Earth switch 2 Feeder Earth switch Feeder
On/OFF On/OFF On/OFF On/OFF On/OFF On/OFF
Single indications: Q0 1
Q0 1 M
Q0 1 M
M
A5 1 -T1
A5 1 -T1
3
-F1
Short circuit indicator RK1 Short circuit indicator RK2 Fuse blown Grouped Indication Auxiliary power failure Transformer temperature alarm Remote control off UPS failure Station open
A5 1
Meters (optional): Meter feeder
3
Double commands: -T5
Ring unit 1 isolator Ring unit 2 isolator Feeder
-T5
On/OFF On/OFF On/OFF
Analogs (optional): Ring Unit 1
Ring Unit 2
Feeder to LV transformer
Ring unit 1 Current Phase L2 Ring unit 1 Voltage L2-N Ring unit 2 Current Phase L2 Ring unit 2 Voltage L2-N ©
Page 72
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Automation in a MV Ring (1) E1
SB11
SB-R E2
0
SB21
20
SB22
40
60 [sec]
Example of network configuration. The network is divided into four sections. In the example is there a fault between SB21 and SB22. A central control unit is placed with the circuit breakers (E1,E2). The circuit breakers could be taken in and out from the central control unit. Decentral control units are placed with the line switches in each section (SB11,SB-R,SB21 and SB22) .These units get information from a voltage sensing system and control each line switch. In a ring configuration it is a must to have a voltage sensing system on both sides of the line switch. ©
Page 73
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Automation in a MV Ring (2) E1
SB11
SB-R E2
0
SB21
20
SB22
40
60 [sec]
With a fault in the network configuration, the protection relay will take the circuit breaker (E2) out. The central control unit will try to put the circuit breaker in, but in a faulty network configuration the protection relay will take out the circuit breaker again. ©
Page 74
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Automation in a MV Ring (3) E1
SB11
SB-R E2
0
SB21
20
SB22
40
60 [sec]
This procedure indicates to all units (SB21,SB22 and SB-R) that the network configuration is faulty, and the automatic sectioning starts. All decentral control units (SB21 and SB22) take out the line switches .
©
Page 75
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Automation in a MV Ring (4) E1
SB11
SB-R E2
0
SB21
20
SB22
40
60 [sec]
The central control unit closes the circuit breaker after 20 seconds, to test the first part of the network configuration .
©
Page 76
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Automation in a MV Ring (5) E1
SB11
SB-R E2
0
SB21
20
SB22
40
60 [sec]
After 40 seconds the decentral control unit (SB21) closes the line switch.
©
Page 77
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Automation in a MV Ring (6) E1
SB11
SB-R E2
0
SB21
20
SB22
40
60 [sec]
Because this part of the configuration (SB21 – SB22) is faulty, the central unit will take out the circuit breaker. The decentral control unit (SB21) discovers that the voltage only was in for a short time, and then takes out the line switch and locks it. ©
Page 78
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Automation in a MV Ring (7) E1
SB11
SB-R E2
0
SB21
20
SB22
40
60 [sec]
The decentral control unit (SB22) discovers that the voltage was in only for a short time, and because of the voltage sensing system of both sides of the switch, the unit knows that the fault is between SB21 and SB22. The decentral control unit (SB22) will then lock the line switch. ©
Page 79
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Automation in a MV Ring (8) E1
SB11
SB-R E2
0
SB21
20
SB22
40
60 [sec]
The decentral control unit (SB-R) have detect the start of the automatic sectioning. The decentral control unit (SB-R) has not detected any voltage on the side SB-R – SB22. After a time (60 seconds) the unit knows that the fault is between SB21 and SB 22, and the line switch (SB-R) is closed. Now at this time the part between SB21 and SB22 (the faulty) is disconnected from the healthy part of the network configuration. © Page 80
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Automation in Rural Areas Sectionalizer ©
Page 81
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizing in Overhead Lines
Sectionalizer enable a system for automatic sectioning in a network configuration. Automatic sectioning is based on switching on and out line switches and circuit breaker in a controlled sequence to find errors in the network. When the errors are found, the system will take out the faulty part of the configuration.
©
Page 82
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizing in Overhead Lines S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
Circuit breaker
Load-breaking switch
Power Transformer
Voltage sensing system
Example of network configuration. The network is divided into six sections (S1 – S6) ©
Page 83
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (1) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
With at fault in the network configuration, the protection relay will take out the circuit breaker. ©
Page 84
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (2) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
The central control unit (E1) will try to put the circuit breaker in but in a faulty network configuration. ©
Page 85
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (3) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
100
80
120
140 [sec]
The protection relay will take out the circuit breaker again. ©
Page 86
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (4) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
This procedure indicates to all units (E1 and L1 .. L5) that the network configuration is faulty, and the automatic sectioning starts. The automatic sectioning starts at relative time 0 seconds. All decentral control units (L1 .. L5) take out the line switches . ©
Page 87
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (5) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
The central control unit closes the circuit breaker after 20 seconds, to test the first part of the network configuration (S1). ©
Page 88
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (6) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
After 40 seconds the decentral control unit (L1) closes the line switch. ©
Page 89
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (7) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
Because this part of the configuration (S2) is faulty, the central unit (E1) will take out the circuit breaker. ©
Page 90
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (8) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
The decentral control unit (L1) discovers that the voltage only was in for a short time, and then takes out the line switch and locks it. At this time the section S2 (the faulty) is disconnected from the healthy part of the network configuration. ©
Page 91
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (9) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
After 60 seconds the central unit (E1) closes the circuit breaker.
©
Page 92
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (10) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
The decentral control unit (L2) closes the line switch in due to the voltage sensing system. ©
Page 93
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (11) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
After 80 seconds the decentral unit (L3) close the line switch in due to the voltage sensing system. ©
Page 94
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (12) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
After 100 seconds the decentral unit (L4) close the line switch in due to the voltage sensing system. ©
Page 95
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (13) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
Because this part of the configuration (S4) is faulty, the central unit (E1) will take out the circuit breaker. ©
Page 96
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (14) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
The decentral control unit (L4) discovers that the voltage only was in for a short time, and then takes out the line switch and locks it. At this time the section S4 (the faulty) is disconnected from the healthy part of the network configuration. ©
Page 97
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (15) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 S2: 250 kW
0
20
40
60
80
100
120
140 [sec]
After 120 seconds the central unit closes the circuit breaker and the automatic sectioning is finished. The decentral control unit (L5) could be designed to close the line switch after 120 seconds. ©
Page 98
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer (16) S4: 250 kW
e. g. 110/ 20kV
L3 S5: 250 kW
S1: 500 kW
E1
L2
S3: 375 kW
L4
L5
S6: 150 kW
L1 See next page
S2: 250 kW
0
20
40
60
80
100
140 [sec]
120
The central control unit sets outputs (lamps) for each section (S1 – S6) which is faulty. It is also possible to send this information to a network control system via IEC 6870-5-101 protocol, or/and send SMS messages. ©
Page 99
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sectionalizer: Switch and Control
Line Switch with voltage transformer
Electronic with storage battery, local control and communication
©
Page 100
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (I)
Tuesday, Jan 29, 2008 Section 1: Goal, task and aspects of distribution automation Section 2: Impacts on planning of distribution automation Section 3: Selection of substations to work under automation –
automation
layout Section 4: Which parameters should be measured or controlled ? Section 5: Selection criteria for hardware, software and communications Section 6: Distribution automation standards
©
Page 101
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Power Systems Control and Energy Management Multi-Level Environment Integrated utility business operation
F&A
Asset Energy Sales Management Data & Care Warehouse
MIS
...
Business Services
Enterprise Integration Bus
Added value network management & optimization
Meter data Advanced applications Network Network management information (EMS, DMS, EBM, Trading) planning
...
(applications and systems)
Network control & supervision
DB
SCADA etc.
Gateway IT Integration
Information gateway
(single-or multi-utility)
ASP Administration
Partner, market, etc.
$Trader
Operation Private & public networks
Communication
Power Exchange
Multi-site
E-Commerce Maintenance
Field data acquisition, Local automation local control & automation
Substation Protection RTUs automation
Meters xxxx x xxx xxx xx
©
Page 102
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Communication Media
Optical Fiber
Public Network
Copper Cable
GSM/CDMA – Network
Radio
Power Line ©
Page 103
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Backbone Network / Access network MV - Line RTU
RTU
Backbone Network
RTU
MV - Line
RTU
RTU RTU ©
Page 104
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Backbone Network / Distribution Data Acquisition
Control Center
TCI
No. Z
No. 1 Optical Fibre
MV - Line
RTU
MUX
RTU RTU Page 105
©
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Aspects of Network Design
Costs
Reliability
Network Design
Regulations
Performance ©
Page 106
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Communication Selection Criteria Leased Public Line The
telephone company provides direct point-to-point connectivity between the RTU location and the control centre. On both end of the communication, a suitable modem appropriate to bandwidth (9600 bauds, 86 Kbps) is required.
The
cost of the communication of this nature comprises the fixed cost to be paid as one-time charges (for Registration fees, Installation fees of the equipment) and the operational charges (for periodical subscription as well as usage).
Though
this type of communication facility seems to be economical, on a long term it may not turn up to be cost-effective, since one has to pay the periodical operation charges.
The
other disadvantage is due to frequent failures of the lines, dependence of third party state-owned service provider.
This
type of communication has limitations for future expansion as the number of RTUs / mRTUs increases. © Siemens AG 2008
Page 107
Jan 2008
Dr. Roland Eichler
Power Transmission and Distribution
Communication Selection Criteria Dial-up Public Line
Few
telephones / modems are provided having dial-up facility at the control centre end, whereas at the RTU / mRTU ends the modems are to be provided with answering facility.
For
a real-time operation, this kind of communication is not preferred due to the time consuming dial-up and answering process. However, for Automated Meter Reading or for checking the status of reclosers after disturbances dialup communication can be effectively utilized.
The
cost of the communication of this nature comprise of the fixed cost to be paid as one time Registration fees, Installation fees of the equipment) and the periodical subscription as well as usage charges.
Disadvantages,
however, are the same as indicated above for the ’Leased line communication’. ©
Page 108
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Communication Selection Criteria GSM Mobile Communication
With
the advent of mobile telephony, usage of GSM communication is becoming quite popular and widely used for data communication. Using GSM modems at the RTU end and the Control Centre end the data exchange can be introduced using urban mobile (GSM) networks.
While
considering the GSM network as a feasible solution one has to be sure that mobile connectivity is available at all the RTU locations.
GPRS
is also an acceptable solution.
Disadvantages
are similar as indicated above for leased line communication. Even more, GSM networks tend to be overloaded during peak hours and might make RTU communication unavailable for quite a while.
©
Page 109
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Communication Selection Criteria Digital Networks via Fiber Optic It
is required to lay extensive FO cables connecting primary stations, subdivisions and the control centre. Such systems, though “The Best” technical option to establish a TCP/IP network, requires considerably high cost. In addition to establishing of an extensive FO network, the associated terminating equipment and multiplexers are required at all the location from where the data is to be collected or to be dropped in. Though the solution does not look to be cost effective at first sight due to high initial costs, it may turn out to be cost effective, if the utility makes use of the extra fibers of the FO cable for other communication facility requirements such as voice, Fax, other IT applications. With the establishment of an own FO network, the utility has the responsibility for operation and maintenance of the network, but at the same time it has full control of system expansion in case of increasing number of (field-) RTUs. Fast wireless Ethernet modems are gradually becoming popular. The Ethernet modems are available in the rated range of 5 miles to 25 miles. Making use of such Ethernet modems together with FO based communication network as backbone, makes an ideal communication between distribution substations, receiving substations and the control centre. ©
Page 110
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Communication Selection Criteria Radio Communication The
communication system using radio requires considerably high costs associated with procurement of radio systems, installation of towers and masts for antennas etc.
However,
once installed and put into operation, the communication system has low, annual costs for operations and maintenance. Thus it helps the utility to establish its own communication network.
It
is necessary to obtain the frequency allotment / approval from the wireless agency or the prescribed authority as nominated by the state / govt. In general, yearly subscription fees for utilizing the frequency are required to be paid.
Before
implementing the solution, a detailed Sight of Line study is required to be carried out for the feasibility of the solution in a particular town / city. Obstruction make occur due to high rise buildings (also by not yet existing ones !). ©
Page 111
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Costs
Hardware Commissioning / Installation Base fees Connection fees Excavation work
©
Page 112
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Cost Comparison Telecontrol service (RTU) and remote load profile reading
Connection fee
Invest for assembly and operation
Base fee Assembly/commisioning
1800%
Hardware cable Hardware equipment
1600% 1400%
9 km MV line with 4 kiosks
1200% 1000%
Over 5 years 12 polling per day
800% 600%
PLC over Medium Voltage
400% 200% 0%
dio Ra
e r) BT ow adio t R (no
C
I M DC r) CD line al) ble a C GS f c e a S ( S (lo tc ne l mod DC DC ilo ine ed li p l a i w s D ed Ne ea as L e L
*) This calculation depends on the regional conditions, the example based on the European / African market.
Transmission method ©
Page 113
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Data Transmission with Distribution Line Carrier (DLC)
©
Page 114
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Data Transmission with Distribution Line Carrier (DLC) - Inductive coupling device Conductor 1 Conductor 2
Conductor 3
Sealing end
Earthing strap
CDI (ferrite ring)
Earthing bar
BU
The coupling transformer encloses the earthing strap of the MV cable ©
Page 115
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Data Transmission with Distribution Line Carrier (DLC) - Capacitive coupling device Conductor 1
Conductor 2
Conductor 3
Connecting element
CDC
Earthing bar
Bracket or separate supporting bar for CDC
Cable outlet ©
Page 116
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Data Transmission with Distribution Line Carrier (DLC) – Basic Unit Communication Multi carrier principle Transmission in the frequency range of
CENELEC Uniform hardware for Master & Slave Transmission rates up to 28.8kbit/s (depending on the line) Bypass of MV switchgear Simple & complex: MV line, tree or ring networks Interfaces Telecontrol per IEC 60870-5-101 or DNP 3.0 Meters per IEC 61107 Medium-voltage line and telecontrol line ©
Page 117
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Data Transmission with Distribution Line Carrier (DLC) – Sample project: MEA Bangkok/Thailand
Control center
MV substation automation - field trail DLC runs with microRTU and control center by using IEC communication standard Test with out-door CDC coupling units Transmission rate 9.6kBd
Distribution point V.24
Pole mounted switch 1
Pole mounted repeater
Pole mounted switch 2
IEC 60870-5-101 V.24
MasterBU
BU MV Line
IEC 60870-5-101
V.24
BU
BU MV Line
©
Page 118
Jan 2008
IEC 60870-5-101
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Data Transmission with Distribution Line Carrier (DLC) – Sample project: MEA Bangkok/Thailand
Mounting a BU cabinet on an overhead line pole
Pole mounted cabinet including DCS3000 BU
Fully-installed cabinet, with DCS 3000 BU and SICAM microRTU
©
Page 119
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Power Systems Control and Energy Management Multi-Level Environment Integrated utility business operation
F&A
Asset Energy Sales Management Data & Care Warehouse
MIS
...
Business Services
Enterprise Integration Bus
Added value network management & optimization
Meter data Advanced applications Network Network management information (EMS, DMS, EBM, Trading) planning
...
(applications and systems)
Network control & supervision
DB
SCADA etc.
Gateway IT Integration
Information gateway
(single-or multi-utility)
ASP Administration
Partner, market, etc.
$Trader
Operation Private & public networks
Communication
Power Exchange
Multi-site
E-Commerce Maintenance
Field data acquisition, Local automation local control & automation
Substation Protection RTUs automation
Meters xxxx x xxx xxx xx
©
Page 120
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Basic SCADA/EMS/DMS System Architecture
Interfaces
ORACLE DW
Front End
ELCOM
HIS
SDM
DMS
SA RO
DW EA
SCADA
DSM
NA
PA
DTS
Operational DW Database BASE
ICCP
Interfaces Base
Distribution
Generation
Transmission ©
Page 121
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sample SCADA/EMS/DMS Modularity
Transmission Generation
TNA TNA TS TS
LTOP LTOP Multi Multi BCK BCK
GSA GSA EMM EMM
SDT SDT
Elcom Elcom
Base Base Data Data
SCADA SCADA PA PA
ICCP ICCP GIS GIS
IS&R IS&R DNA DNA
DSM DSM
SCADA
IndC IndC
CFE CFE
UI UI FA FA
GEI GEI
OA OA
Distribution
MultiBck Base CFE Data DNA DSM ELCOM EMM FA GEI GIS GSA ICCP IndC IS&R LTOP OA PA SCADA SDT TNA TS UI
Multisite/Backup System Base System Communication Front End Data Engineering Distribution Network Applications Demand Side Management Electricity Utilities Communication Energy Market Management Forecasting Applications General External Interface Interface to GIS Generation Scheduling Applications Inter Control Center Protocol Industrial Communication Information Storage & Retrieval Long-Term Operation Planning Operational Applications Power Applications Supervisory Control & Data Acquisition Software Development Tools Transmission Network Applications Training System and Simulation User Interface & Operator Support ©
Page 122
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Advantages of SCADA-integrated DMS Applications (I) There are solutions available rather where a separate DMS software is linked to the SCADA system. Integrated DMS applications, however, means software components that have been designed and implemented to form an integrated solution together with the SCADA base system. This provides benefits to the user: Applications obtain current loading/switching states from SCADA Applications are triggered by SCADA (periodically, on event) Switching procedures determined by applications are automatically, fast and securely executed via the SCADA system Closed-loop applications possible (e.g. VVC)
©
Page 123
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Advantages of SCADA-integrated DMS Applications (II) There are solutions available rather where a separate DMS software is linked to the SCADA system. Integrated DMS applications, however, means software components that have been designed and implemented to form an integrated solution together with the SCADA base system. This provides benefits to the user: same user interface - less training effort, staff is productive earlier same system base - no extra cost for dealing with another system base same data model - less effort for data maintenance common database - operator sees consistent values in SCADA and applications, operators have ‘trust’ in the applications, operators actually use the applications and realize their benefits common system environment - applications are easy to use, operators actually use the applications and realize their benefits ©
Page 124
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
System Configuration Non-Redundant All-In-One System
UI RTS CFE PSOS AAS Web TS
: User Interface : Real Time Server (SCADA) : Communication Front-End : Power System Object Server (Data Model) : Advanced Application Server : Web Terminal Server ©
Page 125
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
System Configuration Non-Redundant All-In-One System w/- external UI Clients
UI RTS CFE PSOS AAS Web TS
: User Interface : Real Time Server (SCADA) : Communication Front-End : Power System Object Server (Data Model) : Advanced Application Server : Web Terminal Server ©
Page 126
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
System Configuration Non-Redundant Dual-Server System
UI RTS CFE PSOS AAS Web TS
: User Interface : Real Time Server (SCADA) : Communication Front-End : Power System Object Server (Data Model) : Advanced Application Server : Web Terminal Server ©
Page 127
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
System Configuration Redundant Multi-Server System
UI RTS CFE PSOS AAS Web TS
: User Interface : Real Time Server (SCADA) : Communication Front-End : Power System Object Server (Data Model) : Advanced Application Server : Web Terminal Server ©
Page 128
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Integration Solution for GIS Interface Rear projection Wall’s 84‘‘ 84‘‘
Support
Support
Operation
Operation
GPS Time system
2 x Laser printer b/w
Laser printer color m-Term
m-Term
to Bckp
SCADA-DMS LAN
to PDS
Router / Modem
IM / ISR IM Server / ISR Server
SCADA-DMS SCADA-DMS Server Server
ICCP ICCP Server Server
Front-end Front-end Server Server
Firewall
Ultimately: IEC 60 870-5-104 Legend: MMI IM/AC ISR FE DMS RTU GPS
Man-Machine-Interface Information Management Information Storage & Retrieval Front End Distribution Management System Remote Terminal Unit Global Positioning System
Support
Serial Serial interfaces interfaces
Web Server
RTU RTU RTU RTU Primary Substations
Initially: IEC 60870-5-101
Corporate Network
GIS ©
Page 129
Jan 2008
Dr. Roland Eichler
SAP
AMR
Siemens AG 2008 Power Transmission and Distribution
Integration Solution for SAP Interface Rear projection Wall’s 84‘‘ 84‘‘
Support
Support
Operation
Operation
GPS Time system
2 x Laser printer b/w
Laser printer color m-Term
m-Term
to Bckp
SCADA-DMS LAN
to PDS
Router / Modem
IM / ISR IM Server / ISR Server
SCADA-DMS SCADA-DMS Server Server
ICCP ICCP Server Server
Front-end Front-end Server Server
Firewall
Ultimately: IEC 60 870-5-104 Legend: MMI IM/AC ISR FE DMS RTU GPS
Man-Machine-Interface Information Management Information Storage & Retrieval Front End Distribution Management System Remote Terminal Unit Global Positioning System
Support
Serial Serial interfaces interfaces
Web Server
RTU RTU RTU RTU Primary Substations
Initially: IEC 60870-5-101
Corporate Network
GIS ©
Page 130
Jan 2008
Dr. Roland Eichler
SAP
AMR
Siemens AG 2008 Power Transmission and Distribution
Integration Solution for AMR Interface Rear projection Wall’s 84‘‘ 84‘‘
Support
Support
Operation
Operation
GPS Time system
2 x Laser printer b/w
Laser printer color m-Term
m-Term
to Bckp
SCADA-DMS LAN
to PDS
Router / Modem
IM / ISR IM Server / ISR Server
SCADA-DMS SCADA-DMS Server Server
ICCP ICCP Server Server
Front-end Front-end Server Server
Firewall
Ultimately: IEC 60 870-5-104
Legend: MMI IM/AC ISR FE DMS RTU GPS
Man-Machine-Interface Information Management Information Storage & Retrieval Front End Distribution Management System Remote Terminal Unit Global Positioning System
Support
Serial Serial interfaces interfaces
Jan 2008
RTU RTU RTU RTU Primary Substations
Initially: IEC 60870-5-101
Meter
redundant
Page 131
Web Server
Dr. Roland Eichler
Corporate Network
GIS ©
SAP
AMR
Siemens AG 2008 Power Transmission and Distribution
Possible control center structural configurations Independent CC’s with different software configuration
Dependent CC’s in Multi-Site configuration, with centralized database maintenance and data exchange
MCC CC 1
CC 1 CC 2
CC 2
CC 3
Independent CC’s with different software configuration and data exchange over ICCP with CC1
?
CC 1 CC 2
CC 3 ©
Page 132
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Multisite Operation of Control Centers Multiple Control Centers in a hierarchical and/or equal-rank configuration can cooperatively manage a power system. Multisite keeps statuses and values in the process images of the Control Centers up-todate with statuses and values from other Control Centers and distributes supervisory control commands, manual updates, tagging and alarm acknowledgments.
©
Page 133
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Multisite Operation of Control Centers Features
Exchange of information between Control Centers Uniform data model and central data management, i.e. reduced maintenance effort Controlling the network from different Control Centers Increased availability Compensation of communication failures (i.e. automatic transmission of missing data after return of the connection) Possibility of delegating operator tasks permanently or during periods where Control Centers are un-staffed or understaffed Provision of backup or emergency systems Simple and fast design of emergency and system management concepts as well as straightforward implementation (configurability)
©
Page 134
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Multisite Operation of Control Centers Basic Concept
The Multisite concept allows connecting two or more control centers to a Multisite network. Hierarchical or equal-rank configurations and also combinations of them are possible. Each control center is autonomous and independent in the Multisite network. The control centers can have different hardware combinations and different data. The hardware configuration of one system is not visible to the software system of other control centers, i.e. each control center is regarded “as a unit” by all other control centers. All control centers are connected to each other via LAN/WAN links. The control centers communicate with each other via TCP/IP.
©
Page 135
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Multisite Operation of Control Centers Basic Concept Control Center Redundancy Multisite features enable control center redundancy, if the information areas of the control centers are defined with an appropriate large overlapping. Two control centers can share the operation control tasks for the same area. Multisite features enable the configuration of an emergency system. For this aim, identical information areas are assigned to both control centers. The hardware configuration and functions need not be identical. Delegation of Operation Control Task The operation control task can be moved between the control centers at request of the operator. This allows operating a control center unmanned during periods when management requirements are low e.g. during night time.
©
Page 136
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Multisite Operation of Control Centers Hierarchical Configuration
Information Information Network Network (RTUs, (RTUs, ICCP, ICCP, ...) ...)
Main Main Control ControlCenter Center
Regional Regional Control ControlCenter Center
Regional Regional Control ControlCenter Center
Regional Regional Control ControlCenter Center
Information Information Network Network (RTUs, (RTUs, ICCP, ICCP, ...) ...)
Information Information Network Network (RTUs, (RTUs, ICCP, ICCP, ...) ...)
Information Information Network Network (RTUs, (RTUs, ICCP, ICCP, ...) ...)
©
Page 137
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Multisite Operation of Control Centers Main/Backup Configuration
Backup Backup Control Control Center Center
Main Main Control Control Center Center
Information Information Network Network (RTUs, (RTUs, ICCP, ICCP, ...) ...)
Information Information Network Network (RTUs, (RTUs, ICCP, ICCP, ...) ...)
Information Information Network Network (RTUs, (RTUs, ICCP, ICCP, ...) ...)
©
Page 138
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sample Main/Backup Configuration Backup CC Link FO Link > 2 MBps
Main
PC
SB
PC
SB
Bckp
Initially: IEC 101 Ultimately: IEC 104 via FO
Port 1
Port 2
RTU
Primary Substations
Independent (dual port) communication between RTU and Main/Bckp The Multisite backup concept allows data entry once for both locations Main and Backup are redundant and self-contained Fully automatic update of databases at both locations ©
Page 139
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sample Main/Backup Configuration Backup CC Link FO Link > 2 MBps
Main
PC
SB
PC
SB
Bckp
Initially: IEC 101 Ultimately: IEC 104 via FO
Port 1
Port 2
RTU
Primary Substations
Normal operation: Port 1 sends to/receives from Main Port 2 sends to Backup Backup is continuously updated from Main (operator entered data) Backup is ready for take-over at any instant of time without any human interaction © Page 140
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Sample Main/Backup Configuration Backup CC Link FO Link > 2 MBps
Main
PC
SB PC
PC
Bckp
SB
Initially: IEC 101 Ultimately: IEC 104 via FO
Port 1
Port 2
RTU
Primary Substations
Disturbed operation: Server fault at ECS standby server at ECS takes over, no other changes, completely transparent to operator Fault of communication link to ECS data to /from the affected RTU goes via the Backup CC Link and BCS, no other changes, completely transparent to operator All servers down at ECS (i.e. incl. spares !) operator at ECS can immediately connect ©
Page 141
Siemens AG 2008
to BCS orEichler operation is performed from Janhis/her 2008 workstation Dr. Roland PowerBCS Transmission and Distribution
System Security IT Trends for SCADA/EMS/DMS
©
Page 142
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
System Security Thread Analysis
©
Page 143
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
System Security Thread Analysis – Potential Attackers
©
Page 144
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
System Security Thread Analysis – Sample Attacks & Countermeasures
©
Page 145
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
System Security Multi Level Security Concept
Interconnection (e.g. to other utility Computer networks, Internet, etc.)
User access to system functionality (none, view, modify)
User Authorization by login
Logging (audit records)
User access rights for controlling the access to the IMM data model ©
Page 146
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
System Security Typical Secure Network Setup
(*)
(*)
Page 147
Support TLS/SSL/PKI Security for ICCP Communications Jan 2008 Dr. Roland Eichler
©
Siemens AG 2008 Power Transmission and Distribution
System Security Sample System Integrity and Confidentiality Methods Adding, deleting and modifying user profiles with an O/S User Administration application of the SCADA/DMS database management system Assigning of user roles to users Runtime verification of user authorities Assigning of ‘Areas of Responsibility’ to users Restricted access by outside parties and security protection against unauthorized attempts to procure internal passwords Mechanisms for data authentication to ensure data integrity (complete and unmodified data) and data privacy Networking and internet security settings, turning off of unnecessary network services All user logon/ logoff activities are logged in the ‘System Alarm Summary’ list Automatic user logoff with configurable timer (configurable) Password security, including encryption of transmitted and stored passwords Administrator security measures that include enabling account lockout methods, renaming the account, establishing separate accounts for multiple administrators, setting up an administrator password control process and configuring of administrator access with critical but limited privileges. © Page 148
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Automation projects are multi-part/multi-technology Bulk Data Management Systems Geographical Information Systems (GIS), Automatic Meter Reading (AMR) systems, etc.
SCADA/DMS Control Center Severs, consoles, large screen projections, etc. HV
Communication Equipment Power Line Carrier, Radio, GSM, etc. MV
MV
R Cable R n.o.
MV
OverheadLine T
Substation Equipment
R
R
S
Meters, Remote Terminal Units, Motorized Switchgear, etc.
R DistributionSubstation NS ©
Page 149
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Automation projects call for particular vendor qualifications 9 DA
systems must be designed as a whole, parts must fit together (interfaces, capacity, redundancy, ...) 9 DA grows over time 9 Must stay open to technology advances during implementation time 9 DA
constitutes a system/solution business (as opposed to a product business)
9 Need
long-term vendor stability 9 Need profound vendor experience in large, complex, multitechnology projects 9 Need profound vendor understanding of business processes in the electricity distribution business ©
Page 150
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (I)
Tuesday, Jan 29, 2008 Section 1: Goal, task and aspects of distribution automation Section 2: Impacts on planning of distribution automation Section 3: Selection of substations to work under automation –
automation
layout Section 4: Which parameters should be measured or controlled ? Section 5: Selection criteria for hardware, software and communications Section 6: Distribution automation standards
©
Page 151
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards The Scope of IEC TC57 scope
To prepare international standards for power systems control equipment and systems including EMS, SCADA, DA, teleprotection, and associated information exchange for real-time and non-real-time information, used in the planning, operation and maintenance of power systems. Power systems management comprises control within control centres, substations and individual pieces of primary equipment including telecontrol and interfaces to equipment, systems and databases, which may be outside the scope of TC 57.
©
Page 152
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Simplified TC57 Groups WG3 – 60870-5 RTU Communications WG7 – 60870-6 Control Center to Control Center Communications WG10 – 61850 Substation Automation WG13 – 61970 Control Center API WG14 – 61968 DMS WG15 – 62351 Security WG16 – 62325 CIM Market Extensions WG17 – 61850-7 Distributed Generation WG18 – 62344 =>61850 Hydro WG19 – 62357 Architecture Standardization activities colored in red are relevant for distribution automation. ©
Page 153
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards IEC 60870-5 series - Overview
©
Page 154
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards IEC 60870-5 series – Details (I)
IEC
60870-5-101 This standard defines the functionality for the interoperability of telecontrol equipment of different manufactures for the communication between substations (outstations) and between substation (outstation) and control centers (central station). Therefore it applies to telecontrol equipment and systems with coded bit serial data transmission for controlling and monitoring geographically widespread processes.
IEC
60870-5-102 It standardizes the transmission of integrated totals representing the amount of electrical energy transferred between power utilities, or between a power utility and independent power producers on a HV or MV network as a part of energy management systems functionality. It is not concerned with LV networks or the interfaces to the energy consumption meters themselves. In general the values of integrated totals are transmitted at periodic intervals to update the energy interchanges. ©
Page 155
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards IEC 60870-5 series – Details (II)
IEC 60870-5-103 This standard is used to upload protection data. It is applicable for substation automation systems with star coupled protection devices using point-to-point links and a master slave transmission procedure.
IEC
60870-5-104 This standard enables Application Data Units, as defined in IEC 60870-5-101, to be transmitted over a variety of digital data networks using the standard TCP-IP transport interface. Thus the specifications of this standard present a combination of the application layer of IEC 60870-5-101 and the transport functions provided by a TCP/IP. Within TCP/IP various network types can be utilised including X.25, FR (Frame Relay), ATM (Asynchronous Transfer Mode), and ISDN (Integrated Service Data Network).
©
Page 156
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Protocol architecture IEC 60870-5-104 vs. 101
©
Page 157
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Simplified TC57 Groups WG3 – 60870-5 RTU Communications WG7 – 60870-6 Control Center to Control Center Communications WG10 – 61850 Substation Automation WG13 – 61970 Control Center API WG14 – 61968 DMS WG15 – 62351 Security WG16 – 62325 CIM Market Extensions WG17 – 61850-7 Distributed Generation WG18 – 62344 =>61850 Hydro WG19 – 62357 Architecture Standardization activities colored in red are relevant for distribution automation. ©
Page 158
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Purpose of IEC 61850 The standard defines a communication system that provides interoperability between the functions to be performed in a substation but residing in equipment (physical devices) from different suppliers, meeting the same functional and operational requirements. Functional requirements are met independent of substation size and operational conditions. The functions of an substation automation system are control and supervision, as well as protection and monitoring of the primary equipment and of the grid. Other functions are related to the system itself, e.g. supervision of the communication.
©
Page 159
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Traditional substation automation system Control Centre IEC 60870-5-101 DNP V3.00
Control Centre
Substation Automation System
IEC 60870-5-104 Time signal Log.IN1
1100
F1
1530 1530
>1 1503 Log.IN2
F2
8888 Log.Out1
2173 2173
Log.IN3 1530
Ethernet
IEC 60870-5-101 DNP V3.00
Modbus/Profibus DP
Profibus FMS IEC 60870-5-103
©
Page 160
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Substation automation system based on IEC 61850 Control Centre
HMI Clients
IEC 60870-5-104 Ethernet
Full Server
Full Server
Stationsbus
IEC 61850 plus Profibus FMS, OPC where necessary
©
Page 161
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Real substation automation system based on IEC 61850 Engineering Workdesk
IEC 60870-5-101
Time synchronization via GPS antenna
Remote access to the engineering work desk via Remote Desktop
Mobile Work desk
SICAM PAS DIP 25/6kV HSA SICAM PAS DIP 110kV HSA 6 kV BSP approx. 10 km
Transformer monitoring IEC61850
SICAM PAS Full Server
Substation bus IEC61850
Bay unit 6MD63 for central I/Os
Field unit 6MD63 for central I/Os
IEC 60870-5-101
Station bus IEC61850 110 kV HSA Equipment
Station bus IEC61850 25/6kV HSA Equipment
Bay unit 6MD63 for central I/Os
Station bus IEC61850 6kV BSP Equipment
Gateway
e.g. IEC 103
Remote substations via SICAM miniRTU
Bay units (7SJ, controller)
non IEC61850based equipment (as needed)
Bay units (7SJ, Controller)
non IEC61850based equipment (as needed)
Bay units (7SJ, controller)
©
Page 162
Jan 2008
Dr. Roland Eichler
non IEC61850based equipment (as needed)
Siemens AG 2008 Power Transmission and Distribution
Standards IEC 61850 Application Fields Today
Control Center
Control Center
Remote Service / Diagnostics
IEC 60870-5101 /-104 Firewall Router
IEC61850 Station Bus IED
IED IEC 61850 (Ethernet) Protection & Control
Hard-wired process interface
©
Page 163
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Full Benefit of Ethernet and IEC 61850 Technology Station bus is one and only communication infrastructure Tunneling of legacy protocols Various network topologies supported Full GOOSE support for inter-bay applications System-wide time synchronization by SNTP System-wide network monitoring by SNMP Remote diagnostics ©
Page 164
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards IEC 61850 Future Application Fields *in standardization work
To be harmonized with CIM IEC 61970*
Control Center
communication to other
IEC 61850
IEC 61850
substatons*
Firewall Router
IEC61850 Station Bus IED
IED IEC 61850 (Ethernet) Protection & Control
IEC61850 Process Bus Digital Instrument Transformer Data via IEC61850-9-2
Merging Unit
CT VT Page 165
Jan 2008
Dr. Roland Eichler
©
Siemens AG 2008 Power Transmission and Distribution
Standards Simplified TC57 Groups WG3 – 60870-5 RTU Communications WG7 – 60870-6 Control Center to Control Center Communications WG10 – 61850 Substation Automation WG13 – 61970 Control Center API WG14 – 61968 DMS WG15 – 62351 Security WG16 – 62325 CIM Market Extensions WG17 – 61850-7 Distributed Generation WG18 – 62344 =>61850 Hydro WG19 – 62357 Architecture Standardization activities colored in red are relevant for distribution automation. ©
Page 166
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards IEC Standard 61970: Goals and Background Goals
of the project:
Reduce the cost and time needed to add new applications to an EMS/DMS Protect the investment in existing applications that are working effectively in an EMS/DMS Background
Information:
¾ International
Standard IEC 61970 is being prepared by IEC Technical Committee 57 ‘Power system control and associated communications’ (WG 13) ¾ The standard defines an application program interface for an energy management system ¾ Part of the IEC Standard IEC 61970 is the Common Information Model (CIM) ¾ The work is based upon the work of EPRI Control Center API (CCAPI) research project (RP-3654-1) ©
Page 167
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards IEC Standard 61970 – Status of May 2006 Stages of Standardization: 1. WD 2. CD 3. CDV 4. FDIS 5. IS
Part
Nam e
Current Version
Current Date
Current Status
1 2
Planned Version
Due Date
Guidelines and General Requirements
First Edition
01.12.2005
IS
Glossary
First Edition
01.07.2004
IS
301
CIM Base
First Edition
01.03.2005
302 401
CIM Energy Scheduling, Reservations, Fi Overview i l CIS and Framew ork
First Edition
01.09.2005
IS
402
Common Services (Base Services)
9
24.05.2006
403
Generic Data Access (Request and Reply )
7
404
High Speed Data Access
6
405
Generic Eventing and Subscription (Events and Subscription) Historical Data Access
Planned Status
Action Required (see note)
IS
Second Ed
01.05.2006
IS
1
CD on hold
3
28.06.1905
CD
1
CDV
10
24.08.2006
FDIS
2
11.07.2005
CD
8
01.05.2006
CDV
1
26.04.2006
CDV
7
24.08.2006
FDIS
2
?
04.05.2006
CDV
?
24.08.2006
FDIS
2
CIM
CIS
407
2 or 3 ?
04.05.2006
CDV
?
24.08.2006
FDIS
2
1a
05.10.2002
WD
2
01.05.2006
CD
1
451
CIS Information Exchange Model Specification Guide (CIS Data Content) SCADA CIS
1
14.05.2003
WD
2
01.08.2006
CD
2
452
CIM Model Exchange Specification
1
11.05.2006
CDV
2
24.08.2004
FDIS
2
453
CIM Based Graphics Exchange
2
19.05.2006
CD
3
24.08.2006
CDV
2
First Edition
450
Formats
2
501
CIM RDF Schema
16.12.2005
FDIS
01.04.2006
IS
7
502-7
1
01.09.2005
WD
2
01.06.2006
CD
1
503-7
Common Services (Base Services) C Lang Profile GDA C Language Mapping
1
15.07.2005
WD
2
01.06.2006
CD
1
552-4
CIM XML Model Exchange Format
6
05.05.2005
CDV
7
01.05.2006
FDIS
7
553-4
CIM SVG Graphics Exchange Format
2
19.05.2006
CD
3
24.08.2006
CDV
1
Notes:
1. Incorporate comments and prepare new version for WG13 review
6. Ready to send to IEC
2. Incorporate comments and send to IEC for circulation
7. Waiting for IEC publication or circulation
3. Need to assign editor 4. Prepare w orking draft 5. Need NWIP
©
Page 168
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards CIM: Relationship to other standards
CIM is:
The
CIM is:
The
CIM is:
The
basis for the Application Program Interface IEC 61970
basis for the emerging inter-system interface architecture IEC 61968 control system data model harmonizing with substation communication based on IEC 61850
©
Page 169
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Simplified TC57 Groups WG3 – 60870-5 RTU Communications WG7 – 60870-6 Control Center to Control Center Communications WG10 – 61850 Substation Automation WG13 – 61970 Control Center API WG14 – 61968 DMS WG15 – 62351 Security WG16 – 62325 CIM Market Extensions WG17 – 61850-7 Distributed Generation WG18 – 62344 =>61850 Hydro WG19 – 62357 Architecture Standardization activities colored in red are relevant for distribution automation. ©
Page 170
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Typical Distribution Utility Roadmap for Tomorrow‘s World Traditional Infrastructure Workforce Management
Integrate Applications
Asset Management
Workforce Management
Asset Management
Outage Management
Trouble Call Center
Extend and Connect
Vendors & Partners Customers Employees
Finance/ Controlling
GIS/NIS Trouble Call Center
Outage Management
Interf. Customer Information System
Finance/ Controlling Customer Information System
GIS/NIS
SCADA/ EMS/DMS
SCADA/ EMS/DMS
EAI Enterprise Application Integration
Network Planning Meter Data Acquisition
Meter Data Acquisition
Portals
EAI Enterprise Application Integration
Energy Data Warehouse
Interface Billing System
Energy Data Warehouse
Network Planning
Billing System
IEC 61968
B2B Marketplaces
Customers
Vendors & Partners ©
Page 171
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards Purpose of IEC 61968 This standard define interfaces for the major elements of an interface architecture for Distribution Management Systems (DMS). This standard identifies and establishes requirements for standard interfaces based on an Interface Reference Model (IRM). Subsequent parts of this standard are based on each interface identified in the IRM. This set of standards is limited to the definition of interfaces and is implementation independent. They provide for interoperability among different computer systems, platforms, and languages. Methods and technologies used to implement functionality conforming to these interfaces are considered outside of the scope of these standards; only the interface itself is specified in these standards.
©
Page 172
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards IEC 61968 Methodology Business Process
Process-Led Design
Process Step Sender Component Receiver Component Information Exchanged
Use Cases
Methodology Logical Data Model Verb Show
Noun Asset
Attribute Definitions Asset.Code Asset.ID Asset.Description Asset.Condition
Message Type Definitions
AttributeApp App A Logical B Model
Information Exchange Models UI Bus. Logic Data
XML FTP CORBASOAP BOD COM EDI
App A
UI Bus. Logic Data
Application Interfaces
App B ©
Page 173
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards IEC 61968 Target Configuration
Grid Wires Model
Information Exchange Model
Outage Reporting Interface Adapter
DAC
EMS
Interface Adapter
Dist Wires Model
OMS
VRU
Distribution Automation
CIS
Interface Adapter
Interface Adapter
...
IEC 61968 Compliant Middleware Services Interface Adapter
Event History
AM/FM/GIS
Human Resources
Work Management
Substation Automation
Data Warehouse
©
Page 174
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Standards TC57 WG19 (founded Jan 2005) Mission: With regards to the CIM (IEC 61970, IEC 61968), and extensions to the CIM that were recommended for IEC 61850, this new working group would be the coordinator of the electronic model for TC57, ensuring harmonization of the expansion of the CIM. Vision: All new TC57 standards should use/extend the CIM as the common semantics for their configuration/engineering modeling, and 61850 for [SCADA oriented / IED / field] communications. Other existing standards would likely take a mapping approach. Services could also be addressed (61850 services, Web Services, security, operations, SOA and GID services could be harmonized). Liaison with CIGRE SC-D2 WG25. ©
Page 175
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
More Standards
SCADA/DMS solution call for further standardized interfaces for stateof-the-art openness to other IT systems ¾SQL/ODBC data access to historical data from Corporate Network ¾ODBC for access from PC client ¾X-11-Window for remote PC console access (in case of Unix O/S) ¾ISDN for remote maintenance access
©
Page 176
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (II)
Wednesday, Jan 30, 2008 Section 7: SCADA functionalities Section 8: DMS functionalities Section 9: Case study presentation Section 10: Distribution system automation personnel skills Section 11: Maintenance and support procedures
©
Page 177
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Front-End
The front-end domain comprises of the components: Interconnections to RTUs Inter Control Center Communication
©
Page 178
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Front End Requirements Reliable and Efficient Process Data Acquisition State-of-the-art standard hardware basis High availability features (line-level redundancy, telegram buffering) Integration of standardized IEC protocols and capability to integrate different supplierspecific RTU protocols Extensive communication diagnostic capability including monitoring and listening modes (protocol-specific) Engineering via the regular SCADA/EMS/DMS database management tool ©
Page 179
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Front-End RTU Interfacing - Tasks Analog Values Change Detection (Hysteresis threshold) Old-/new comparison, time tagging assignment Renewal check (analogues and digitals) Analog Values Zero Suppression Calculation of analog engineering values (linear and non linear characteristic) Analogues filtering (spike suppression, smoothing) General interrogation and completeness check Keeping an RTU real-time database Centralized test & diagnosis Time synchronization of RTUs via protocol ©
Page 180
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Front-End RTU Interfacing – Protocol processing in dedicated HW System Configuration SCADA LAN TCI
TCS
.... HUB (star coupler) TCI LAN TCR TCB 1 1
...
7
...
TCR
TCB 14 1
...
...
7
...
RTU RTU
PS + backplane
RTU TCB : TCR : TCS : PS :
TeleControl Interface Board TeleControl Interface Rack TeleControl Interface Server Power Supply ©
Page 181
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Front-End RTU Interfacing – Protocol processing in the server
Power System Object Server (PSOS)
Real Time Server (RTS)
UI Client SCADA EMS/DMS LAN
Communications Front-End 1 (CFE 1)
Router
Communications Front-End 2 (CFE 2)
Real-Time Data LAN
to RTU
to RTU
Router to RTU
to RTU
WAN
RTU
RTU
Configuration with redundant CFE subsystem and different RTU interface connections ©
Page 182
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Front-End RTU Interfacing – High Availability Requirements
Redundancy Features Server failover to redundant CFE server in case of active CFE server failure Line connection failover to standby line connection in case of a failure of the active line connection Configurable load sharing between two or more CFE servers Supervision of standby line connection (channel), including telegram buffering Maximized availability during engineering Only the required RTUs are affected when changing engineering data ©
Page 183
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Front End Inter Control Center Communication
SCADA/EMS/DMS SCADA/EMS/DMS
(Local (LocalControl ControlCenter) Center)
SCADA/EMS/DMS SCADA/EMS/DMS
Other OtherUtilities Utilities
(Remote (RemoteControl ControlCenter) Center)
(other (othervendor’s vendor’ssystem) system) WAN (or permanent lines)
Non-utility Non-utility Generators Generators
Power PowerPools Pools Regional Regional Control ControlCenters Centers
©
Page 184
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Front End ELCOM-90 (IEC 60870-6 TASE.1)
Supported data objects
Indications and alarms Analog values and counter*) values Archive data Commands Setpoints
Data transmissions mechanisms
Spontaneous data transmission (on value change) Periodic data transmission (e.g. every 10 seconds) Initiated data transmission (initial scan, archive data)
*) Counters are not supported by standard ELCOM, 64-Bit „float“ for counters added by SCADA vendors ©
Page 185
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Front End ICCP (IEC 60870-6 TASE.2) Supported data objects
Indications and alarms Analog values and counter values Archive data Commands Setpoints
Data transmissions mechanisms
One-shot data transmission Periodic data transmission Transmission of event data Transmission of exception data
Security Protocols
Transport Layer Security (TLS) Secure Sockets Layer (SSL) Public Key Infrastructure (PKI) ©
Page 186
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Conformance Block 1 Basic Services
Conformance Block 2 Extended Data Set Condition Monitoring
Conformance Block 3 Blocked Transfer
Conformance Block 4 Operator Stations / Information Message
Conformance Block 5 Device Control
Conformance Block 6 Programs
Conformance Block 7 Events
Conformance Block 8 Accounts
Conformance Block 9 Time series Page 187
Transfer of real-time cyclic data
100%
Transfer of real-time data by exception
100%
Could be a bit matrix transfer for accelerated data transfer. Too risky ?
---
Transfer of messages between control center operators. Can as well be done with tcp/ip based messaging tool. Issues supervisory control operations from the local Control Center to the remote system. Supposed start/stop of a program in control center A from control center B. Too risky ? Block 7 supposed to signal the completion of a Block 5 supervisory command. Use of Block 2 instead is industry standard. Supposed to transfer historian data. Can as well be done via ftp file transfer. Supposed to transfer scheduling data. Can as well be done via ftp file transfer. Dr. Roland Eichler
25%
---
---
8%
--©
Jan 2008
8%
Use of ICCP Conformance Blocks investigated over 40 projects.
Front End ICCP (IEC 60870-6 TASE.2) – Conformance Blocks
Siemens AG 2008 Power Transmission and Distribution
Supervisory Control and Data Acquisition (SCADA)
RTU, ICCP, ELCOM 90
External External Communication Communication
Applications Applications
Wireless Alarming SCADA SCADA
Historical Historical Information Information System System
Energy Energy Accounting Accounting
Alarming Telecontrol Monitoring
©
Page 188
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA SCADA Functions
Data Processing Event and Alarm Processing Marking and Tagging Limit Monitoring Supervisory Control Switching Procedure Management Real-time Accumulator Processing Real-time Calculations Topology Processing
©
Page 189
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Data Processing
Status Data Processing Alarms, States, Normal / Abnormal States, Sequence of Events Analog Data Processing Limit Check, Threshold Adaptation, Max./Min./Ave. Values Accumulator Processing Completeness Check, Authorization Data Calculation Definition of Formulas, Arithmetical / Comparison / Logical / Functional Operators Dynamic Network Coloring Network Topology, Network Groups, Operational Status ©
Page 190
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Event and Alarm Processing
Event / Alarm Administration Operator Alarming, Assignment to Alarm Classes, Technological Area and Responsibility, Consideration of Local/Remote state Event / Alarm Presentation Visual Annunciation in Displays and Summaries, Acoustical Annunciation Event / Alarm Handling and Control Single/ Multiple Acknowledgement, Alarm Suppression Alarm Forwarding Central Control Room Klaxon, Wireless Alarming (SMS, Pager), Escalation Strategy, including Shift Plan and Acknowledgement
©
Page 191
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Supervisory Control Control Device Operations & Execution Monitoring Single switching devices (ON/OFF, OPEN/CLOSE) Tap changers (one step UP/DOWN) Continuously regulating devices (RAISE/LOWER) e.g. of sliders and valves Generator units (e.g. SETPOINT) Two-step procedure for safety reasons (SELECT, EXECUTE) Monitoring of interlocking conditions Security mechanisms e.g. Telecontrol is monitored for timeout of control execution Supervisory Control can be applied by the operator through ¾Substation one-line diagrams ¾Switching Procedure Management (also from applications) ¾tabular displays (runtime explorer) – mainly during commissioning phase ©
Page 192
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Switching Procedure Management
Switching Switching Operation Operation Commands Commands Creation Creation Recording in study context Testing in study context Modification of an existing procedure Fault Isolation and Service Restoration (FISR) Outage Management System (OMS) ...
Switching Switching Procedure Procedure Management Management Switching Procedure Switching Switching Operation Operation Commands Commands Switching Switching Operation Operation Commands Commands
... Switching Switching Operation Operation Commands Commands
Usage Usage
create create edit edit select select sort sort print print execute execute
Prepare, study and execute clearance operations Alleviate fault conditions
Restore power following a fault
store store
©
Page 193
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Switching Procedure Management
Check Check
Create Create
Start Start
Storage Storage
Remove Remove
Approve Approve
Execute Execute
Suspend Suspend // Resume Resume
Archive Archive
©
Page 194
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Switching Procedure Management – User Interface
Step-by-Step preparation using schematic displays Full screen editor for general data Simulation of all switching actions with power flow checks Execution with temporary pause/resume Automatic documentation
©
Page 195
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Topology Processing
Network Status Processing Definition of network groups Distinguished statuses for each electrical phase (energized, grounded, undefined, de-energized, energized uncertain, grounded uncertain) Topological Coloring Coloring of network groups (incl. coupled network groups) Distinguished coloring views (normal/abnormal, energization, voltage level, single/multi phase level, network group, loop parallel) Interactive Topological Tracing The topology processor is activated by each change of a switch device and by topological changes of the network model.
©
Page 196
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Load Shedding Functions Load rejection or disconnection (shedding) of parts of the network Analyzes the state of the network Detects significant events Defines load to be rejected Prepares selected items of equipment for actions Individual configuration of emergency strategies such as Manual load reduction Rotating load reduction Load reduction on underfrequency Load reduction on contract violation Load reduction on equipment overload Load reduction for island stabilization
©
Page 197
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Load Shedding Modes
Fixed wired under frequency Load Shedding
predetermined under-frequency Load Shedding
Load Shedding in Emergencies
Man Machine Interface
Man Machine Interface
PLC e.g. Simatic
Schedule with Control Sequences
Schedule with Priming Sequences
Disturbance Scenario Dependent Switching Tables
remote commands
priming commands
remote commands
Manual Planned Load Shedding
control centre power system under-frequency relay
feeder breaker
under-frequency relay
feeder breaker
latching relay
feeder breaker
feeder breaker
©
Page 198
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Intelligent Alarm Processor (IAP) The Diagnosis provided by IAP includes Date and time of the disturbance Faulty devices/equipments Protection systems which cleared the fault Specifics in the sequence of a disturbance (e.g. breaker failure, automatic re-closer successful / unsuccessful, etc.)
The Input Data for IAP are The topology of the network The alarms from the automatism Logical working schema of the automatism
©
Page 199
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Intelligent Alarm Processor (IAP)
Outage location Outage type Process data
IAP Protection malfunction
Actual topology
Intelligent Alarm Processor
Earth fault location Multiple outages Affected busbars
©
Page 200
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Intelligent Alarm Processor (IAP) - Overview
Once only
EXCEL Forms
Protection System Models Algorithm
Continuous
SCADA
Diagnosis
Events and Alarms
©
Page 201
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA Intelligent Alarm Processor (IAP) – Models used Protection Systems all installed types of protection systems e.g. distance, differential, over-current, etc. various types of a protection system (e.g. distance protection systems with different behaviour) Automatisms ARE (automatic recloser equipment), fault detectors, etc. Gathering by an EXCEL form systematic description of the logic behaviour of protections and automatisms alarms produced by the systems and received in the SCADA Models are defined only once; not affected by data modification; integrated in database management system of the SCADA/DMS ©
Page 202
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Key Requirements (I) Graphic displays High resolution Multi-window technique Fast display response time Java-based User Interface using Java Webstart Menue-guided operation and interactive dialogs Graphically oriented User Interface with extensive standard functions Open system (i.e. access to office automation and engineering on the same screen) Interactive display construction Definable console access rights
©
Page 203
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Access Rights
SCADA security is associated with specific user accounts and based on a combination of: User role (e.g. Control Room; Field Crew; Data Maintenance, …) Domain assignment (e.g. Electricity; Gas; Water; District Heating, …) Access rights (e.g. process control; viewing only; partial modification, …) Areas of responsibility (AOR)
©
Page 204
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Key Requirements (II) Dynamic coloring of Network groups Grounded network parts Network parts with grounded faults De-energized parts of the network Network islands RDBMS Data Access via operational data displays Extensive Web-based Online Help Wireless Alarming (Out of Office Assistant) Improved Alarm Acknowledging ©
Page 205
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Display Types Basic Signaling Display Network Diagrams (Worldmaps) Summaries Tables (Data Explorer) Curve Displays (Curvetool) RDBMS Displays Motif Forms
©
Page 206
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Path Tracing in Distribution Networks
e.g. Trace Up from Distribution Substation
Trace up Trace down Trace between Trace all Trace common point Trace loop Trace parallel ©
Page 207
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Graphical Queries using RDBMS Displays Selecting network areas in a one-line diagram and performing pre-canned queries like Switching states Deviation from normal switching status Attribute date for equipments Power flow values Raster image data The queries can be displayed at predefined places in the worldmap Data in the list can be sorted, filtered and printed
Example: Result of Graphical Queries in a worldmap
©
Page 208
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Basic Signalling Display (Example)
Access to all SCADA/EMS/DMS displays by associated buttons Single signaling by a button on the display Summary signaling (indicated by the color of the respective tab)
©
Page 209
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Network Operation through Context Menu (Example)
Context Menu By right-clicking the selected element and holding down the right mouse button Shows all operations associated with the selected element
©
Page 210
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Data Export through Drag & Drop
Simple data export through copy & paste to MS Word MS Excel MS Outlook or other mail programs
©
Page 211
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Representation of a Worldmap by its Planes
Station C
Station D
plane 1 network level
Station A Station B
zooming
plane 2 sub network level
Station A
Station B
zooming
plane 3 110kV 0A
station level
230A
Station A zooming
Transformer 1
plane 4
Transformer 2
Transformer 1 zooming
feeder level
Transformer 110kV/20kV Next inspection 06.09.1993
©
Page 212
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Zooming Example
Layer 1 Network Overview Layer 2 Network Connectivity
Layer 3 Substation Connectivity Layer 4 GIS Information
©
Page 213
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Large Screen Projection
Visibly yours
Video, RGB signals
EOS Controller NT/2000 Application Client e.g. SINAUT® Spectrum
LAN Terminals
©
Page 214
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Concept Study: Navigation capabilities
Jump to Google Earth
Jump to Worldmap
©
Page 215
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Concept Study: Geo-referencing of substations and lines
• Localization of substations • Support for fault location
©
Page 216
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Concept Study: Geo-referencing of crews and assets
• Crew location • Work order • Asset tracking ©
Page 217
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Concept Study: Integration of external data
• Trouble tickets • SLA time ranges • Routes, borders, etc. ©
Page 218
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Concept Study: Integration of weather data
• • • •
Rain radar Cloud development Forecast Storm warning ©
Page 219
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface Concept Study: Geographic reporting
• Power Quality • Quality of Service ©
Page 220
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface GIS Integration
GIS
SCADA/DMS Sub 3 rot
GG EE OO TAG TAG
120A 50%
22 kV 22 kV 180A 60%
Sub3 2
Layer 2 Network Connectivity
21 kV
GIS GIS Import Import Tools Tools
Layer 3 Substation Connectivity
N V 0k ..1 Y. e.
TAG/TA TAG/TA Table Table
Av ill H V st k re .10 Fo Y.. N
A A T T T T R R I I B B U U T T E E
Rules Rules
Layer 1 Network Overview
rot
Layer 4 Mapping Information
©
Page 221
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface GIS Integration - Import of Attribute Data (1st Step)
SCADA/DMS Database
3)
IDDUG files
Import 3)
Attribute Data
Export
GIS
Attribute Data
Bulk or incremental ©
Page 222
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface GIS Integration - Import of Geographical Data (2nd Step)
SCADA/DMS Database
Geographical Data
dxf files 1)
Import 2,3)
GIS
Geographical Data
X
IDDUG files
Import 3)
Attribute Data
Export
Schematic Data
Use geographical displays only
UI Software
Attribute Data Real-time Data
1)
More formats available Autograph format 3) Bulk or incremental 2)
©
Page 223
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface GIS Integration - Use of imported geographical data (1/3)
Sub 3 rot
Geographical Data
2
Layer 2 Network Connectivity
Layer 3 Substation Connectivity
Attribute Data
e.
Import
Sub3
21 kV
Av ill H V st k re .10 Fo Y.. N
Schematic Data
120A 50%
22 kV 22 kV 180A 60%
V 0k ..1 Y. N
Import
SCADA/DMS Database
Layer 1 Network Overview
rot
Layer 4 Mapping Information
©
Page 224
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface GIS Integration - Use of imported geographical data (2/3)
Display Level 1 "Overview" (Primary Feeder, HV/MV Substations, Network Groups)
Sub 3
red
blu e
Display Level 2 "Network Connectivity" (Primary and Secondary Feeder, all Distribution Substations)
red
green
Sub 1
Sub 2
120A 50%
22 kV 22 kV 180A 60%
Sub3
21 kV
Display Level 3 "Substation Connectivity" (all Buses, Switches)
©
Page 225
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface GIS Integration - Use of imported geographical data (3/3)
120A 50%
22 kV 22 kV 180A 60%
Sub3
Display Level 3 "Substation Connectivity" (all Buses, Switches)
21 kV
Transformator....... Leistungsschalter.... .. FWG ......
Window with Display Level 4 "One-Line Diagram" Window with "Facility Data"
V 0k ..1 Y. N e. Av ill V H 0k st . 1 re Y.. Fo N
Display Level 5 "Mapping Information"
Geographical Display
©
Page 226
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface – Case Study Iberdrola/Spain: Example for incremental download of data and graphics from GIS
GIS
All data is maintained solely in the GIS Use powerful tools there and save money Both schematics and geographics ‚live‘ available in SCADA&DMS
SCADA/EMS/DMS
©
Page 227
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface – Case Study Iberdrola/Spain: Example for incremental download of data and graphics from GIS
GIS
SCADA/EMS/DMS
©
Page 228
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
User Interface – Case Study EPM/Columbia: Example for ‘living’ geographical SCADA&DMS displays
©
Page 229
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval (IS&R) Key Requirements Easy operability (graphic user interface) High data availability Easy reconstruction of historical data Consistency of stored data (primary and derived data) Open interfaces to other systems (e.g. SQL, ODBC, etc.) The system provides services to transfer historical and future data to an ORACLE database
©
Page 230
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval (IS&R) Components of IS&R Data storage (periodic or spontaneous) Data retrieval By means of predefined queries (archive filters) it is possible to retrieve values of different time ranges and storage cycles from archives.
Modification of stored data Defined dependencies of individual values (formulas) are automatically updated when any of the involved values changes.
Interface for long-term archiving SQL interface for external data exchange Export interface to a RDBMS (ORACLE) ©
Page 231
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval (IS&R) Data to be archived Analoge values or accumulator values with time stamp Calculated values Switching state changes and alarms Data of the network topology Forecast values Trend data Disturbance data (including switching states) Schedules
©
Page 232
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval (IS&R) Archiving Functions Data reduction via technological filtering Cyclical archiving Spontaneous storage of status data changes (e.g. for network reconstruction) Visualization of stored values as curves, logs, or single values in one-line diagrams (network displays) Correction of archived data including recalculation of derived data Online initialization, modification and deletion of archives Trend data archives Post mortem review No loss of data during failover of archive server
©
Page 233
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval (IS&R) Embedded Reporting Functions Report layout definition via editor Periodic output and output on demand Reports may include worldmap display segments (worldmap segments are automatically scaled) Report management tool Output of reports to printers, file or operator consoles
©
Page 234
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval (IS&R) SQL Interface Provides the capability to access various types of data of the SCADA/EMS/DMS The SQL interface can be used for operational, planning and administrative purposes Access to the data can be performed using standard Structured Query Language (SQL) statements (data import / export) For further data analysis also 3rd party products (e.g. Microsoft EXCEL) can be used The type and precise scope of the exchange can be configured freely by the user
©
Page 235
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval Archive System for Disturbance Data
Disturbance Data Collection Disturbance Disturbance Data Data
Continuous Continuous Data Data Collection Collection
Archive Archive System System
Trigger Event
Trigger configuration Use any field device (i.e. any alarming condition) as trigger Assign to a trigger which data will be collected Define the collection time interval of the assigned data (pre-trigger, post-trigger)
©
Page 236
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval Overview
Sources • Front-end • SCADA
Remote Console
Local Console
HTTP Server
Incoming Incoming Data Data Analogs Analogs Digitals Digitals Calculations Calculations Accumulators Accumulators Events/Alarms Events/Alarms
Offline Offline Archive Archive
Disturbance Disturbance Data Data Online Online Archive Archive
Data Data Collection Collection Buffered Buffered for for Redundancy Redundancy
Oracle Oracle DB DB
Long Long Term Term Archive Archive
External External Reporting Reporting ©
Page 237
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval Connecting External Report Tools
Sonstige projekt-/ External Data kundenspezifische Access Systeme ASCII, z. B. CSV
Excel RepGen Report Generator
WOP Direct Data Interface via SQL Internet/Intranet (ADO, ODBC, JDBC) Access
External Applications
FDWH Data Warehouse & Report Generator Analogs Digitals Administrator Tool based on ORACLE
SCADA
Direct Data Interfaces via SQL (ADO, ODBC, JDBC)
Other customer specific systems
Remote Metering Systems
External Data Access ASCII, z. B. CSV
External tools for reporting or web access may also connect directly to the Oracle archive of the SCADA system. © Page 238
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval Connecting External Report Tools
SCADA Archiving Servers
LAN Firewall
Web-Server with WebAccess/ WOP and ReportGenerator for automatic reporting
Firewall
FDWH-Server with ORACLE database
Office LAN
Office PC with ReportGenerator an/or Webbrowser
Office PC with ReportGenerator an/or Webbrowser
©
Page 239
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval Sample External Report Tool
based on MS Excel simple report definition w/o database knowledge processing of data (e.g. graphics) with all available Excel features complex queries with SQL and macros possible capabilities for automated reporting
©
Page 240
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Storage & Retrieval Sample Web Access Tool
online access via browser filter capabilities graphical and tabular display capabilities export to csv-files simple formula editor
©
Page 241
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (II)
Wednesday, Jan 30, 2008 Section 7: SCADA functionalities Section 8: DMS functionalities Section 9: Case study presentation Section 10: Distribution system automation personnel skills Section 11: Maintenance and support procedures
©
Page 242
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Functionality Overview
Enterprise Integration Bus Distribution Network Applications
Optimal Feeder Reconfiguration
GIS Operation Applications
Geographical Displays
Fault Isolation/ System Restoration
Dynamic Network Tracing
Outage Management System
Dynamic Network Coloring
Switching Procedure Management
Large Network Displays
SCADA
Volt/Var Volt/Var Dispatch Distribution Power Flow
Open Archiving & Reporting
©
Page 243
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Operation Applications Operations Applications (OA) is a suite of modules that enable the operator to view outages and to effectively manage resources to restore the electrical network. The OA component provides the following functions: Outage Management System (OMS) Trouble Call System (TCS) Crew Management System (CMS)
©
Page 244
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Outage Management System (OMS) OMS Characteristics Collection of functions, tools and procedures for outage management Supports the detection, location, isolation of faults, and restoration of service Manages unplanned outages or faults as well as planned outages
OMS Requirements Quick and safe localization, isolation of faults and restoration of service within the power system Handling of planned outages, e.g. for preventive maintenance, to increase the supply reliability and to reduce the system operation risks and costs ©
Page 245
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Unplanned Outage Life Cycle
Fault Fault Detection Detection & & Outage Outage Record Record Creation Creation
Fault Fault Location Location
Crew Crew Assignment Assignment
Reports Reports && Statistics Statistics Generation Generation
OMS OMS Database Database
Outage Outage Record Record Archiving Archiving
Fault Fault Isolation Isolation
Fault Fault Repair Repair
Outage Outage Record Record Closing Closing
Restoration Restoration of of Service Service
©
Page 246
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Planned Outage Life Cycle
Outage Outage Schedules Schedules Creation Creation
Switching Switching Procedures Procedures Generation Generation
Crew Crew Assignment Assignment
OMS OMS Database Database
Execute Execute Planned Planned Work Work
Outage Outage Record Record Closing Closing
Generation Generation of of Reports & Statistics Reports & Statistics
Outage Outage Record Record Archiving Archiving
©
Page 247
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Outage Management System - Interfaces
Fault Fault Location Location Application Application (FLOC) (FLOC) Fault Fault Isolation Isolation & & Service Restoration Service Restoration (FISR) (FISR)
Outage Outage Management Management System System
Switching Switching Procedure Procedure Management Management (SPM) (SPM) Trouble Trouble Call Call System System (TCS) (TCS)
Crew Crew Management Management
©
Page 248
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Unplanned Outage Life Cycle Operation Application
FLOC OMS Fault Fault Detection Detection &&
Fault Fault Location Location
Outage Outage Record Record Creation Creation
CMS Crew Crew Assignment Assignment Reports Reports && Statistics Statistics Generation Generation
OMS
FISR Fault Fault Isolation Isolation
OMS OMS Database Database
SPM
Outage Outage Record Record Archiving Archiving
OMS
Fault Fault Repair Repair Field crew activity
Outage Outage Record Record Closing Closing
Service Service Restoration Restoration
OMS
FISR
SPM
©
Page 249
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Planned Outage Life Cycle Operation Application
Outage Outage Schedules Schedules Creation Creation
Switching Switching Procedures Procedures Creation Creation
OMS
SPM
CMS Crew Crew Assignment Assignment
Execute Execute Planned Planned Work Work
OMS OMS Database Database
Outage Outage Record Record Closing Closing
Reports Reports && Statistics Statistics Generation Generation
OMS
©
Jan 2008
OMS
Outage Outage Record Record Archiving Archiving
OMS
Page 250
Field crew activity
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Outage Management System - Requirements
Scheduled and unscheduled outages Outaged equipment, energy, customer An Outage Record can be initiated by Trouble Call System Switch Trip Operator
Reports and statistics by ORACLE reports Documentations of all Switching (Date, Status, Operator, affected Network Area, List of all Switching) Creation of an Outage Data Set for every Disconnected Equipment ©
Page 251
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Outage Management System - Requirements
Calculation of Quality of Service Indices System Average Interruption Frequency Index SAIFI System Average Interruption Duration Index SAIDI Customer Average Interruption Duration Index CAIDI Average Service Availability Index ASAI
Calculation of Outaged Energy Export to Excel
©
Page 252
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Fault Location (FLOC)
Handles outage faults (i.e. short-circuit faults) and non-outage faults (i.e. earth faults) Responds to state change of fault indications and on feeder CB’s unexpected tripping For fast localization of faulty section Designed to determine the smallest possible faulted section based on available real-time information Paramount to restore supply fast and to as many customers as possible
©
Page 253
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications FLOC Processing
Uses remote metered and manually updated information such as: Protective devices’ tripping (CB’s, re-closers, etc.) Status of fault passing indicators Status of earth fault relays Trouble calls
©
Page 254
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications FLOC Methods
Combine available status info Determine the smallest faulted segment Determine boundary switches
Immediate Search
t1a-5 t1a-4
Substation
Protective Device1 t1-1
t1a-3 Protective Device1a
t1a-2
t1-4
t1a-1
t1-3 t1-2
t1c-4
Protective Device1c
t1-5
t1c-3 t1c-2 t1c-1
t1-6 t1-7 t1d-1 t1d-2
t1-8
t1-9
Protective Device1d
t1d-3 t1d-4 t1d-5
Procedural Search
Extends the “immediate search” by trial switching operations Narrows down the faulty segment; e.g.: bisection search ©
Page 255
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications FLOC Results
Fault Records
Record automatically created Includes all equipment in faulty segment Includes boundary devices
Graphical Rendering
Highlighted in one-line diagram: Fault Passing Indicators’ status Faulty feeder segment Related non-faulty segments
Additional Information
Suggested trial switch actions to locate the fault more accurately Procedural search history Summary of fault records
©
Page 256
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications FLOC Event Record
©
Page 257
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Crew Management System (CMS)
Provides tools to view, create and modify crew information and to assign field crews to work tasks Provides timing statistics about multiple field crews CMS works in close relationship to the Outage Management System (OMS)
©
Page 258
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Crew Management System (CMS)
Crew Composition Assigning of people and equipment to the crew Crew Tracking Support of crew and truck locations Crew Statistic Report Processing OMS Interface Association with outage records
©
Page 259
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Distribution Network Applications Distribution Network Applications (DNA) comprise the following functions:
Fault Isolation/System Restoration Distribution Power Flow Feeder Reconfiguration Volt/Var Control
©
Page 260
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Fault Isolation/System Restoration (FISR) Once the faulty segment has been identified (e.g. by FLOC): Finds out how to isolate the faulty segment Finds out how to restore power to all related non-faulty segments Minimizes the outage time for the affected customers Establishes the series of required switching operations Useful also when network is not in faulty condition (e.g. equipment isolation for planned maintenance) Uses the topological model of the network to generate the required switching procedures
©
Page 261
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications FISR – Requirements
Fault Isolation
Service Restoration
Isolation & Immediate Restoration Restore to Normal
Equipment to isolate selected by operator or from FLOC results Minimize the number of switching steps Provides the possible ways to restore service and the corresponding steps Feasibility validation and solutions’ ranking based on performance indexes Combines the two above features Generates a single switching procedure Generates a switching procedure that restores the given network part to its normal configuration
©
Page 262
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications FISR – Output
Tabular Output
Switching steps of the procedure Total kW load restored (incl. the number of transformers/customers) Total kW load not restored (incl. the number of transformers/customers) Violations (voltages & overloads) Total power losses Index for difficulty to access or operate
Graphical Output
Follow-up of switching actions involved in procedure can be done within the one-line diagrams
©
Page 263
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications FISR – User Interface
©
Page 264
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Distribution System Power Flow (DSPF)
Purpose: Continuously checks the distribution network for voltage problems / overloads Allows to detect overloads or voltage problems before they occur in the course of Switching Procedure Management in Study Mode Provides the basis for further applications that reduce distribution network losses
©
Page 265
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Distribution System Power Flow (DSPF)
For 3 phase unbalanced and balanced power systems Real time and study mode Execution Periodically Upon change in the network and On Demand Robust current injection algorithm Calculation of Feeder Profiles: V, A, MW, MVAR and Losses Total Losses Detection of Limit Violations ©
Page 266
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications DSPF – Load Estimation
In distribution networks (sparsely measured) the accuracy of the power flow results relies much upon the quality of the load estimates
Load Curve Data
Loads derived for time and date of the study Generic load curves for different consumers’ types (residential, commercial, industrial, etc.) Loads with constant P or I or Z Hourly load profile over several seasons and day types
Load Modeling
Conforming loads calculated based on peak value and load curve Loads calibration with available RT measurements at injection source, feeder-head or along the feeder Reactive load based on cos ϕ ©
Page 267
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications DSPF - Results
Tabular Output
Busbar kV, voltage imbalances Slack bus P & Q & V Line & transformer P & Q (from & to nodes) Line losses (kW/kVAr), voltage drop Resulting P & Q Loads Small Gen unit P & Q & V Violations (voltages & overloads) Total power losses
Graphical Output
Network coloring in one-line diagrams for voltage violations and branch overloads
©
Page 268
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Volt/Var Control (VVC)
Important function for dealing with the complexity of voltages’ and reactive powers’ control in a modern distribution system Used to support the control of transformer tap (LTC, voltage regulators) and switchable shunt reactive (typically capacitors) Optimize the objective functions for the whole system Improves results against local control only solutions (where coordination problems exist and Volt/VAr optimization opportunities are missed by not taking into account the whole power system) Eliminates local trade-off (e.g. no need for controllers’ dead-band and time delays to avoid oscillation) that reduce efficiency of the Volt/VAr Control
©
Page 269
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Volt/Var Control (VVC)
The objectives of the VVC function are to minimize power loss, or to minimize power demand, or to maximize generated reactive power while satisfying voltage and loading constraints VVC uses the same power flow model as DSPF Allows working with a subset of the network Operates in either realtime or study mode Output: Summary of power flow before and after optimization Recommended Control Actions on transformer tap position changers, line voltage regulators and switchable shunts (in the form of a SPM procedure) ©
Page 270
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications VVC – Sample Output Display
©
Page 271
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Optimal Feeder Reconfiguration (OFR)
The objectives of the OFR function are minimization of power losses, or balancing of substation transformers, or a weighted combination of the above while satisfying voltage and loading constraints OFR uses the same power flow model as DSPF Allows working with a subset of the network Operates in either realtime or study mode Output: Summary of power flow before and after optimization Reconfiguration switching procedure (SPM)
©
Page 272
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications DSPF/VVC/OFR Execution Control Display
©
Page 273
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Non-Technical Losses (NTLO)
The NTLO application is based on: Read Meters (billed energy) ¾Taken over from SAP and fed into the SCADA&DMS Oracle database via middleware
Distribution Transformer Loads ¾Calculated online by DSPF power flow
©
Page 274
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications NTLO – Typical Results
Non-Technical feeder level Feeder Name
losses
EBI
in
10.09.02 – 16.10.02
Non-Technical losses [kWh]
Eval. Days (EBI days)
Transformer list
[%]
Alparos
5487
23
36 (36)
Tereal
5300
25
35 (36)
Helui
4900
21
36 (36)
Percentage of Total Feeder Energy
NTLO points the operator to the most prominent spots of revenue losses. ©
Page 275
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications NTLO – Typical Results EBI
Distribution transformers with highest non-technical losses. Feeder: Alparos
Distribution transformer name (TA)
10.09.02–16.10.02
Non-technical losses [kWh]
[%]
alpa/24ds/traf1
759
3.2
alpa/24ds/traf2
617
2.6
alpa/24ds/traf3
601
2.5
Percentage of Total Feeder Energy
NTLO points the operator to the most prominent spots of revenue losses. ©
Page 276
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Expert System - Advanced Network Operation (ANOP)
Advanced Network Operation (ANOP) uses a specially developed algorithm in order to generate the optimal solution for the following tasks typical in a Distribution Network Unplanned outages / disturbances
Fault Isolation and Network Restoration
Planned outages
Reconfiguration of the network without interruption of customer supply
Corrective measures
In emergency cases the removal of overloads and under voltages, in planned cases the relief of equipment loads
Normal switching status
Reconfiguration of the network to come back to normal switching status
Contingency evaluation
Analysis of the case of a failing equipment including the appropriate counteractions ©
Page 277
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Expert System - Advanced Network Operation (ANOP) Required Features Availability of a fully prepared switching sequence together with additional comments The switching sequence totally fulfils the given task (e.g. no further checks, etc. by the operator) Enables immediate and automatic execution of the switching sequence Provision of such a solution which has passed all checks and does not violate any operational or electrical restriction Presentation of a balance of typical values of interest such as transformer loading, voltage, transferred load, etc. The shown values are the values which will be obtained after the execution of the switching sequence ©
Page 278
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications ANOP Application Example – How to use Operator describes task Select equipment on MMI Select task ANOP evaluates solution for task Switching job Load Balance Operators executes task Execute switching job
©
Page 279
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Trend towards Distributed Energy Generation
New Generation Technologies
Increasing Energy Consumption world wide
Distributed Energy Generation
Political Targets
Increasing Energy Costs ©
Page 280
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications Virtual Power Plants
Network Control System
Decentralized Energy Management System DEMS
Energy Exchange Billing
G
Biomass Power Plant
Meteorological Service Communication Network
G
Block-type Heating Power Plant Flexible Loads Meter Reading PV Power Plants
Data Concentrator Mod.
Mod. Mod. Mod.
Mod.
Mod.
Z
Z Z
Fuel Cells
Distributed Small Fuel Cells
Wind Power Plants
Z
Z
Distributed Loads ©
Page 281
Jan 2008
Dr. Roland Eichler
Z
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications DEMS – Functional Requirements
Energy management system for planning, optimization and monitoring of decentralized power units
Load forecasting system for very short-term forecasts (1 hour) and short-term forecasts (up to 7 days)
Forecasting system for the generation of wind power plants and photovoltaic
Generation/Load Scheduling & Control functions covering all flexible units like contracts, generation units, storages and flexible demands, maximizing the difference of revenue minus costs, i.e. the profit.
Energy data management for collecting and keeping the required information, e.g. loads, contractual data
Powerful front-end for the communication of the energy management system with the decentralized power units. ©
Page 282
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications DEMS – Functionality
Load Forecast
Generation scheduling
Generation Control
Basic SCADA Communication Front End
Renewable Energy Forecast
User interface
Archiving
Load scheduling
DEMS
Reporting
Communication System ©
Page 283
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution Management Applications DEMS – Interfaces SIMATIC Protocols Profibus, Modbus
DEMS
OPC, DDE SQL Database, ODBC Excel and ASCII Files XML Interface for Time Series COM / DCOM Interface Communication Network TCP / IP ©
Page 284
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (II)
Wednesday, Jan 30, 2008 Section 7: SCADA functionalities Section 8: DMS functionalities Section 9: Case study presentation Section 10: Distribution system automation personnel skills Section 11: Maintenance and support procedures
©
Page 285
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Selection of distribution substations for automation Question (A): Automation Rate (IV) Substation retrofitting and adaptation calculation 45 15
35
10
30 5
25 20
0 15 10
-5
Net Present Value, NPV [MUSD]
Average interruption time [minutes]
40
5 0
-10 0
250
500
750
Number of adapted substations
1000
1500
2000
4000
Interruption dependancy NPV
In this study case the optimum automation rate is about 12%. ©
Page 286
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Selection of distribution substations for automation Study case data Average outage time: 40 minutes. Around 650 feeders are supplying around 4000 distribution substations. That is an average of 6.2 distribution substations per feeder.
Average cost for retrofitting & adaptation of one (1) distribution substation in:
30,000 US$.
Number of substations that can be retrofitted per year, without serious consumer interruptions and additional costs: 250 Study period considered:
23 years
(average from 25 years for automation equipment and 15 years for communication equipment) ©
Page 287
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA&DMS reference project: PowerGrid Singapore SCADA&DMS for the entire 22kV network, with more than 3,000 substation RTUs (commissioned 1988) Extension to the 6.6kV network started 1994 with additional more than1,000 substation RTUs Unique communication solution for 6.6 kV substation RTUs using Distribution Line Carrier over cable sheath
©
Page 288
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
PowerGrid Singapore‘s benefits from SCADA&DMS
Enhance reliability and service quality
Provide speedy restoration of supply Minimize/eliminate revenue losses (due to forced consumer outages) Enhance operational efficiency and safety
Reduce operating cost e.g. man power Minimize operational errors Improve assets utilization
Maximize return on existing investment Make timely new investment
©
Page 289
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
SCADA&DMS reference project: PowerGrid Singapore Experience
Commissioning SCADA&DMS on 22 kV
Extension to 6.6 kV
Average Interruption Time Experienced by Customers in a Year ©
Page 290
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (II)
Wednesday, Jan 30, 2008 Section 7: SCADA functionalities Section 8: DMS functionalities Section 9: Case study presentation Section 10: Distribution system automation personnel skills Section 11: Maintenance and support procedures
©
Page 291
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Distribution System Automation Personnel Skills Computer HW/SW Electronics
Power System Operation
Modeling & Algorithms
Communication
Supervise and control the distribution network
Basic
Expert
Basic
--
Keep the SCADA / DMS running at required level of performance
Expert
Basic
Basic
Basic
Role
Control Room SCADA/DMS Maintenance & Administration
Task
Collect and continuously update data required in the SCADA/DMS
Field Engineer and Technician
Design, plan, erect, commission & maintain field automation equipment
Medium
Medium
--
Basic
Communication Engineer and Technician
Design, plan, erect, commission & maintain field communication equipment.
Medium
Basic
--
Expert
Telecontrol Engineer and Technician
Design, plan, erect, commission & maintain RTU, Substation Automation and Front-end equipment
Medium
Basic
--
Medium
Power System Analyst
Define models and data needed for the SCADA/DMS, develop new algorithms.
Basic
Medium
Expert
--
©
Page 292
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Seminar Contents (II)
Wednesday, Jan 30, 2008 Section 7: SCADA functionalities Section 8: DMS functionalities Section 9: Case study presentation Section 10: Distribution system automation personnel skills Section 11: Maintenance and support procedures
©
Page 293
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Testing Concept
Depending on the purpose of testing different concepts are necessary
9Point to point tests during commissioning and revision work (adding, extending or modifying of RTU; reconfiguration of communication network) 9RTU tests 9Communication path tests 9Test of data model modifications when expanding or modifying network configuration 9Functional system test when upgrading or modifying functionality (e.g. patch, release upgrade) 9Testing of new operational practices
©
Page 294
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Testing Concept Object-in-Test Tag 9During commissioning and revision work, the equipment at site must be tested under operational conditions. This means that the whole way from the device outside till the data processing in the control center must be tested and documented.
9The (test) information sent in this phase to the control center has to be processed in another way than the ’real’ process data. This means usually: No alarming, no archiving.
9For this purpose a flag 'Object In Test' can be used. Before starting the revision the flag is set by the operator on all devices which shall be tested. After the test the flag will be removed by the operator.
9The data related to objects flagged as ‘in test’ are displayed in a separate summary. The information are displayed in the one-line diagrams to ensure that the graphical representation is working properly.
9The tag OBJECT IN TEST has the same impact concerning alarming as the tag ALARM INHIBIT.
9After finishing the work the separate summary can be saved to document the commissioning or revision work. ©
Page 295
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Testing Concept Using Contexts other than Real-Time
Run-Time
Engineering
Real- Time
Study
Planning
IMM Suite
IMM Suite
DOR
DOR
App Suite
App Suite
App Suite
App ASR
App ASR
App ASR
Save case repository Save Save Save Case Case Case
Saving a save
Initializing from a case
A context is a user's specific view on a set of resources (variable information /data) that models the working environment (workspace) and its behavior. Contexts satisfy the operational, planning, testing and other activities of the SCADA/EMS/DMS. A context consists of a set of software packages, data sets and displays that are necessary to run a complete functional subset of the SCADA/EMS/DMS. This set of context components works with a consistent view of power system data and the perceived time. Contexts are differentiated from each other by their sources of data and their use. ©
Page 296
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Testing Concept Using Contexts other than Real-Time 9The Realtime Context is used to monitor,
Run-Time
Engineering
Real- Time
Study
Planning
IMM Suite
IMM Suite
DOR
DOR
App Suite
App Suite
App Suite
App ASR
App ASR
App ASR
Save case repository Save Save Save Case Case Case
Saving a save
Initializing from a case
control and manage the domain process. The real-time context provides direct operator interaction with the external world. This is the only context that allows control commands to the external world. Only one real-time control context can be active in the system. 9A Study Context is used to support the operators during different network analysis and operational activities, independently or in parallel to their realtime activities. An example is running load flow studies. 9A Planning Context comes with its own data model i.e. it allows testing of changes to the data model (without changes to RTU data or communication data) in parallel and independent of the other contexts. ©
Page 297
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Testing Concept Using a Separate Testing/Development System
OTS
Testing & Development (TDS)
MAIN
• IEC 870-5-101 • IEC 870-5-104 • non IEC protocols
OTS-LAN
IS&R
• IEC 870-5-101 • IEC 870-5-104 • non IEC protocols
EMS-LAN
PDS-LAN
DMZ-LAN
MultiportRouter 1
MultiportRouter 2
CC-LAN non trusted
IS&R : Information Storage& Retrieval
IT-LAN non trusted
OTS : Operator Training Simulator
.... 1
2
.... 7
1
RCC 2
7
. . . .
RCC 7
©
Page 298
Jan 2008
Dr. Roland Eichler
CC WAN
2
CC WAN trusted
RCC 1
IT WAN
Siemens AG 2008 Power Transmission and Distribution
Testing Concept Using a Separate Testing/Development System 9TDS is a separate system, that runs a test context on separate hardware, allowing tests completely decoupled from the real-time context. An exception is the front-end which might be shared between MAIN and TDS in some cases
9TDS runs either the complete or a subset of the functionality of the MAIN. The deployment of the test system may differ from the deployment of the MAIN (e.g. no redundancy, configuration with less servers).
9TDS can ¾interface data via listen mode from the MAIN or ¾get directly information via its own Front-End. In each case the control direction is usually locked i.e. supervisory control actions need to be simulated without interfering with the real process (e.g. bypass process interface). Successful and not successful reply as result of remote control needs to be simulated.
9TDS can be used for testing of ¾new RTUs ¾new data models ¾new/upgraded software ©
Page 299
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Model Management
SDM (Source Data Management) manages the input of the data of the electric power system into the database of the power control system. SDM is used both during commissioning of the system and afterwards for subsequent modifications and extensions of the network (new substations, changes to the network, etc.). It is important that a single tool provides the functionality to enter and maintain all power system-related as well as computer system-related data.
©
Page 300
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Model Management Object Data Model
Standard Object Types Standard delivery with the product
Standard Object Types Customer-defined Objects Types Customer-entered Objects (Instances)
Examples: Generator, Transformer, Tariff contract, Server
Customer-defined Object Types Examples: Customer generator, Created while the project is being carried out Customer Provides all the required additional object types transformer, adapted contract pattern A, (templates) configured server
Dependent on industry sector and division
Customer-entered Objects (Instances) Are entered by the user during the data input phase and describe the user process (networks, power stations, etc.) Based on prepared object types (templates) All the data points build on it (instances) Are further maintained by the user
Examples: Customer generator West-A, Customer transformer XY, Contract 23 according to contract pattern A
©
Page 301
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Model Management Engineering Process Engineering Phases System Configuration Hardware
Customization Definition of new
Data Entry Import/Export
Network
Instances
XDF/RDF File
Servers
Attributes
SVG File
Software
Associations
3rd PP (Oracle...)
Graphic Objects
SCADA/EMS/DMS SW Mapping to HW
System
Editing … Instances
Adding Project Specials via API
Links Network Diagrams
System-Wide Settings User Administration
Tailoring System Delivery
Adapting Data, adding Project Specials
Day to Day Activities
repetitive use ©
Page 302
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Model Management Functional Overview
Common Information Model CIM Job Management Fully graphicoriented data editing Workflow oriented and Wizard-based technologies Syntactic and generic data validations Import/Export On-line Activation Reports
©
Page 303
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Model Management Advantages from RDBMS Use
Standard query language SQL Easy modification and extension of the data base scheme Comfortable tools available - graphical user interface - report generator The data model is independent from the physical data storage Available functions for - Transaction management - Data integrity - Security and access rights - Backup and recovery - Distributed data bases ©
Page 304
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Model Management Requirements on Job Management
Job Management allows multiple and simultaneous data modifications without any impact on the runtime system Job Interlocks prevent multiple users from editing the same data Automatic change detection generates Change Log files describing all changes Activation of a job transfers the changed data to the run-time system and notifies those applications affected by the change A clearly laid out Job History bookkeeping (e.g. job creation, job activation, undo) is available ÎQuick,
easy and secure data maintenance
ÎNo
interrupt of process control during on-line activation and undo function ©
Page 305
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Model Management Job Management & Data Validation
Extensive Data Validation before start of activation in on-line system Syntactic and generic data validations, which can be extended by user-defined constraints ©
Page 306
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Model Management Principle of Online Database Changes Input and checking of the data is performed in the source database, so that current online data and online system operations remain unaffected. Once entered, prepared and checked, the set of data within a job can then be activated at a time convenient to the operator. Activation means the takeover of modified data from the source database to the operational database, without interruption of system operation and without losing any manually entered data. Data activation is coordinated automatically with all subsystems or activities of the SCADA/EMS/DMS. As an example, it is impossible for an IMM engineer to activate a data modification for a breaker while a supervisory control action is active for this device. Activation includes updating of all servers of the SCADA/EMS/DMS, precisely coordinated with online system operation. After activation newly entered data (e.g. status information, analogue values, station feeders, or entire substations) can immediately be called up and displayed by the operator.
©
Page 307
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Information Model Management Integration with Enterprise Data Model Management Aggregation of enterprise data sources and software applications through common industry standards.
Distribution Apps
GIS
SCADA
Protection Coordination
Assets/ Work Order Systems
Front/Back Office
Integration Bus
Enterprise Data Model Management
Power Flow
On-Line Ratings
Transmission Reliability
Stability PSS/E Model Data High-Speed Data Files
Files
©
Page 308
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
Bibliography on Distribution Automation
©
Page 309
Jan 2008
Dr. Roland Eichler
Siemens AG 2008 Power Transmission and Distribution
View more...
Comments
