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SCADA and Metering UPDEA - Workshop

SCADA and Metering UPDEA - Workshop. Topics. What we measure Substation configurations – and our evolution Four level control vision SCADA Data Types Graphical data display Telecontrol Standard Metering Common Information Model. What does SCADA stand for?.

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SCADA and Metering UPDEA - Workshop

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  1. SCADA and Metering UPDEA - Workshop

  2. Topics • What we measure • Substation configurations – and our evolution • Four level control vision • SCADA Data Types • Graphical data display • Telecontrol Standard • Metering • Common Information Model What does SCADA stand for? SCADA – Supervisory Control and Data Acquisition

  3. What do we Measure? 3 1 4 2 2 1 = Voltage Transformers 2 = Breaker 3 = Line Traps 4 = Current Transformers Primary and secondary plant status and indications

  4. Primary and Secondary data • HV Yard • Trfr Status • Trfr Output • Bkr State • Line Flows • Isolator state • Health data • Protection data • Local Information states What is the key to efficient SCADA systems? • LV Yard • Trfr Status • Trfr Output • Customer load • Bkr State • Isolator state • Health data • Protection data • Local Information states • Power Station • Unit Status • Unit Output • AGC state • Gen Breaker

  5. Key to reliable SCADA functionality A resilient telecoms backbone underpins the SCADA and Metering process. To be effective, substation data must be collected real time and on time! Overloaded comms links cause trouble in a disturbance. Independent consumption metering is ideal. What are the four types of SCADA data?

  6. SCADA provides: 260 160 4 1 & 3 Pole Generator Bay VENUS 250 140 Feeder Bay • Status Data • Two-State Device Control such as circuit breakers, isolators, etc. • Single-State such as alarms • Six state devices, such as auto reclose relays • BCD Tap position • Analogue Data • Megawatts, Mvars, kV, water level, flow rate • Accumulator Data • Power station sent out Megawatts and Mvars • Supervisory control • Device Control such as, breaker control, Auto manual. • Setpoint Device Control, Auto Reclose Relay setting • Pulse control such as AGC up or down, tap change control • Static Var Compensator voltage or Mvar set point

  7. Substation Configuration and Evolution

  8. Substation ID Substation ID Distribution SMART TEMSE Port IEC 60870-5-101 STABNAC Gen 1 Gen 1 Sub-Station 04 Sub-Station 04 CPU Memory 0 0 500 500 0 0 500 500 IRIG-B GPS Receiver Transformer Protection Panel 400 400 0 0 1 1 2 2 500 500 0 0 1600 1600 0 0 12 12 Estel Remote Terminal Unit 12 12 HMI 200 200 Station RTU CPU 200 200 100 100 100 100 Memory 100 100 120 120 220 220 220 220 Munic 2 Munic 2 Munic 1 Munic 1 Sub-Station 02 Sub-Station 02 Todays Configuration Class 1 data collected within 5 milliseconds of state change. Alarm any unauthorized change in the network within 4 seconds. Time stamped data accurate to 1/1000 second

  9. Remote Terminal Units ERTU Bay Processor

  10. Substation ID National Control TEMSE IEC 60870-5-101 Distribution ABB DMP3 STABNAC IEC 60870-5-101 Gen 1 Sub-Station 04 CPU Memory 0 500 0 500 IRIG-B D25 Bay Controller Transformer Protection Panel 400 0 1 2 500 D400 0 1600 0 12 D25 Bay Controller Estel Remote Terminal Unit 12 200 IEC 61850 LAN Station RTU ] ] ] ] ] ] CPU ] 200 100 100 Memory 100 120 220 220 Munic 2 Munic 1 D20 Station RTU Sub-Station 02 ] ] ] ] ] ] ] ] ] ]]]]]] ] ] ]]]]]]]]]]]]]]]] ]]]]]]]]]]]]]]]] ]]]]]]]]]]]]]]]] ]]]]]]]]]]]]]]]] ] ] ] ] ] ] ] ] Tomorrow’s Configuration GPS Receiver HMI

  11. Substation Control System in 10 Years Local HMI (via Browser) Remote Engineering via GPRS link to Substation LAN Technical Services Distribution ABB DMP3 National Control TEMSE IEC 60870-5-101 Local Engineering via Substation LAN PPP GPS Receiver Station Level + - (S)NTP Time Synchronization IEC 61850 Station LAN ] ] ] ] ] ] ] Bay Level Bay Level AC/DC Supply ] Comms ] ] ] ] ] ] Process Level ] ] ]]]]]]]]]]]]]]]] ]]]]]]]]]]]]]]]] ]]]]]]]]]]]]]]]] ]]]]]] ] ]]]]]]]]]]]]]]]] ] ] ] ] ] ] ] ] ]

  12. Breaker and a half Perseus 765 kV Feeder 6 Mercury 1 234 132 Transformer 21 Reactor 6 150 765KV busbar 1 Transformer 21 765KV Interconnector busbar 765KV Mercury 1 Interconnector busbar 765KV Reactor Transfer busbar 765KV Beta 1 Interconnector busbar 765KV Gamma 1 Interconnector busbar 765KV busbar 2 150 150 Busbar Reactor 1 Reactor 3 Feeder 3 Gamma 1 234 132 300 200 300 200 Feeder 2 Hydra 1 Feeder 1 Beta 1

  13. Four Level Vision

  14. Four Level Vision National Standby Control Centre Control Centre Distribution Control Centre #1 Substation Substation Control #n Control #1 Reticulation Reticulation Control #1 Control #n TEMSE TEMSE IEC 60870-5-101 Level 1 Future Inter Control Centre Protocol SMART SMART Distribution Level 2 Control Centre #n DMP3 Protocol ERTU ERTU Level 3 PMRTU Estel Variant Protocol PMRTU Level 4

  15. Levels 1- 4 • Level 1 : National and Standby control centres (220kV to 765kV). • Level 2 : Distribution control centres (33kV to 132kV). • SMART (Standard Master for Regional Telecontrol). • Level 3 : Substation control systems • Based on the Enhanced Remote Terminal Unit (ERTU) being replaced GE Harris D400 Gateway. • Level 4 : Reticulation control. (33kV and below). • Final link in the chain of supply to the end customer. • Includes pole mounted SCADA (PMU) systems protection purposes and permit sectionalising of lines when attempting to isolate faults.

  16. Pole Mounted Units • A pole mounted RTU (PMRTU) is based on conventional SCADA principles and has 3 main elements: • stand alone central controller or master station • a number of remote terminal units in the field • a UHF radio based communications network. • The RTU acts as the interface to the pole mounted devices with a mechanical actuator where no built-in telecontrol interface exists. • Uses a common protocol, known as the Estel Variant protocol. • The current central controller can act as a stand alone device.

  17. SCADA Data Types

  18. SCADA Data Types Bay 1 Status Data • Two-State or double bit Device such as circuit breakers, isolators, etc. • Single-State such as alarms and indications • Six state devices, such as auto reclose relays. • BCD Tap position indication 1 Sect 1 A B 1/275 CPLR 1 2 5 2/275 500280 Trfr 1 M 1280 3 12 Aut 1/400 CPLR 2 2/400 Atlas 2 4 1 & 3 Pole 500280

  19. Double Bit Points – RTU side Double Bit points have a different meaning at the RTU and at the front ends You need two bits for each state for two state devices at the ERTU, e.g. a breaker S X Open = 0 1 Close = 1 0 In transit = 0 0 Don’t Believe = 1 1 (S = Status, X = extended) At the ERTU two bits are used to indicate the combined state of the device. Double bit indication RTUs x n CPU Memory 12 v 1200/9600 b/s X.21 Rapid re-routing communications cloud X.21 Front Ends Front Ends TCP/IP Double bit State Back Ends How many bits are used to model a 2 state device in the SCADA back end? HMI HMI HMI HMI HMI

  20. Front end the bit states: S X Open = 0 0 Close = 1 0 In transit = 0 1 Don’t Believe = 1 1 Extended bit X = Health Status bit S = Device Double Bit Points – DB side • You need two bits for each state for two state devices at the ERTU • S X • Open = 0 1 • Close = 1 0 • In transit = 0 0 • Don’t Believe = 1 1 • Extended bit X = Health • Status bit S = Device Why is it necessary to do a conversion at the Front End from 2 bits to 1 bit for the state of the device? We only want one structure in the data base for single bit and double bit values.

  21. Six Bit status devices • We have Six State ARC relays that have 6 states. • Four of the states are controllable • The states are • Manual • Closing off • 1 Pole • 3 Pole • 1 + 3 Pole • Unknown Controllable • In what form is the data sent back to the control room? • How should it be represented at the RTU? • How should it be represented in the data base?

  22. Six Bit status devices 0 0 0 = Closing Off 0 0 1 = 1 Pole 0 1 0 = 3 Pole 0 1 1 = 1 + 3 Pole 1 0 0 = Manual 1 0 1 = DBI 1 1 0 = DBI 1 1 1 = DBI 0 1 2 3 4 5 6 7

  23. Hexadecimal Where does the word Hexadecimal come from? • Hex = 6 • Decimal = 10 • Hexadecimal = Number 16 • Byte = 8 bits • Nibble = 4 bits • Bit = 1 binary digit What is an 8 bit number is called? Octal = 8 bits

  24. 0 0 0 000 1 1 0 001 2 2 0 010 3 3 0 011 4 4 0 100 5 5 0 101 6 6 0 110 7 7 0 111 8 8 1 000 9 9 1 001 10 A 1 010 11 B 1 011 12 C 1 100 13 D 1 101 14 E 1 110 15 F 1 111 Hexadecimal N10 N16 23 22 21 20 What is the value of an 8 bit number when all the bits are 1? 8 Bits = 1111 1111 = FF = 27 = 255 Or 1 0000 0000 - 1 = (28 -1) = 256 - 1

  25. The BCD Number System is used to measure tap positions where the decimal numbers 1 – 10 have specific bit values in the Hex format. Binary Coded Decimal What number format is used to measure are tap positions?

  26. Each decimal digit is assigned to 4 bits. It is NOT a number base in the sense that binary, octal and hexadecimal are Leading 0s must be included as they are vital to the conversion. Binary Coded Decimal How are numbers represented in BCD format? N10 N16 23 222120 0 0 0 0 0 0 1 1 0 0 0 1 2 2 0 0 1 0 3 3 0 0 1 1 4 4 0 1 0 0 5 5 0 1 0 1 6 6 0 1 1 0 7 7 0 1 1 1 8 8 1 0 0 0 9 9 1 0 0 1 What would the BCD encoding for the number 127 be: H T U 0001 0010 0111 1 0 0 = 100 2 0 = 20 7 = 7

  27. Binary Coded Decimal • Examining Hex values which Hex numbers are not used in BCD coding? • What are the equivalent Hex values of these numbers. • The binary patterns 1010 through 1111 do not represent valid BCD numbers, and cannot be used. • A, B,C,D,E

  28. Binary Coded Decimal • Where do use BCD formats and why? • What would be the range of the numbers needed • What is the numerical value of the bits in position 5 and 4 (25 2423 22 21 20) • What is the BCD value of 31 • Transformer Tap Positions • Normally between 1 and 32 • 10 and 20 • 11 0001

  29. Substation Analog values Megawatt Mvar Amps Voltage Frequency Transformer oil temperature (actual values) Transformer Tap position Conductor Temperature (New) Dam Water Level Derived analog value alarms Area Loads Tap changer rate of change SCADA Data Types - Analog 260 160 4 VENUS Generator Bay 250 140 Feeder Bay

  30. Digital to Analog Conversion + 2000 MW CT VT - 4000 Counts Analog + 4000 Counts + 1000 Counts Analog MW Mvar - 2000 MW RTU Host I/O Transducer Digital Counts If the counts from the ERTU is 1000 what is the engineering value? y = mx + c where m = 2000 : c = 0 4000 Y = 2000 x 1000 + 0 4000 = 500 MWs

  31. Graphical data display

  32. Alarm Data Categories All data points are assigned to one four alarm category types i.e. Health Non Unit Protection Unit Protection Information Following an examination of substation data the following data categories were identified • Health ( Only real Alarms) • Unit Protection • Non – Unit Protection • Information • Device state • Communications • Analog • Tap position • Station • Secondary AC/DC

  33. Abnormal State Propagation Region State Region Substation counts n Health n Main Prot. etc. n Backup Prot. n Substations etc. n Information etc. Device State Element counts Station State Device Substation Bay counts n Health n Health n Main Prot. n Main Prot. etc. n Backup Prot. n Backup Prot. n Bays etc. n Information n Information etc. Four Icon Categories Bay State Bays Device counts n Health n Main Prot. Element data by category n Devices n Backup Prot. etc. n Information etc. Notify the control staff of existence abnormal conditions on the station one line diagrams Allow them to examine the abnormal data when they want to. Upwardly summate the category counts and display the counts as icons at each level.

  34. One line display showing device, bay and station icons The station bay has active health alarms Isolators has health and information icons Transformer had a fault and tripped. Note the device information icon next to the Transformer as well as the parent Transformer Bay and at next to the station name.

  35. Bay State – What is it? MOLL IED 2 1 3 Gen 1 .AND. Venus Jupiter Atlas IED BKR .AND. Bay State 0 400 MOL1 IED 0 320 .OR. IED MOL2 (MOLL & BKR) & (MOL1 | MOL2) & (kV | MW | Mvar) 400 2 Bay 0 1 320 0 1600 0 12 12 100 200 5 120 120 7 4 6 Munic 1 Munic 2 Majuba • Bay States • Disconnected : All links open (Don’t care about BKR ) • Isolated : Bus links closed – Line Link Open • Connected : Links closed – BKR Open • Dead : Link & BKR Closed kV <= 0 • Energised : Link & BKR Closed kV > 0 • On load : Link & BKR Closed MW > 0 • Bypass : Bypass Link closed , Line link open • Mvar only : Links & BKR Closed MW = 0 and Mvar > 0 • Unknown : Analogs <> Status • Increasing (s) : Value is approaching limit (20 min) • Increasing (f) : Value is approaching limit (10 min) • Will Trip in 5 : Bay will trip bay in 5 minutes Do we tell the control staff about the breaker state when the bay is disconnected?

  36. Bay State Benefits

  37. Tele-control Standard

  38. Isolator_1 01_State 10_State Category Type Bin Aud Ctl Isolator State Closed Open Info Double Log_only True Pole Disagree Normal Health Single Protect Isolator_201_State10_StateCategoryTypeBinAudCtl Isolator State Closed Open Info Double Log_only True Pole Disagree Normal Health Single Protect HV_BKR01_State10_StateCategoryTypeBinAudCtl AC Supply Failed Alarm Normal Info Single DC_Sup Breaker Failed to Trip Alarm Normal Main Single Breaker Yes Breaker State (ERTU) Closed Tripped Info Double Breaker Yes True Breaker Unhealthy Alarm Normal Health Single Breaker Bus Zone Trip Alarm Normal Info Single Bus_Zone Yes DC Supply Failed Alarm Normal Health Single Panel Earth Applied Alarm Normal Health Single Panel External to Unit Protection Operated Normal Main Single Protect Pole Disagree Normal Health Single Protect Protection Abnormal Alarm Normal Health Single Protect Protection Operated Alarm Normal Main Single Protect Protection Unhealthy Alarm Normal Health Single Panel SF6 Gas Critical Alarm Normal Health Single Breaker Yes SF6 Non-urgent Alarm Normal Info Single Breaker Supervisory Isolated Off Info Single Panel Transformer Standard (1)

  39. Current Trfr01_State10_StateCategoryTypeBinAudCtl SF6 Gas Critical (CT) Alarm Normal Health Single CT Yes SF6 Non-Critical (CT) Alarm Normal Health Single CT Transformer01_State10_StateCategoryTypeBinAudCtl Amps Info Analog Panel No False Megavars Info Analog Panel No False Megawatts Info Analog Panel No False Tap position Info BCD Trfr No True Bucholz Alarm Normal Health Double Trfr Cooling Failed Normal Health Single Panel Differential Protection Alarm Normal Backup Single Panel Oil Level Low Normal Health Single Panel Over Current/Earth Fault Alarm Normal Main Double Panel Restricted Earth Fault Alarm Normal Main Single Panel Tap (a/m) State Auto Manual Info Single Log_only True Tap out of Step Alarm Normal Health Single Trfr Temperature High Normal Health Single Panel Transformer Standard (2)

  40. Metering

  41. Metering Scheme Components LOAD SUPPLY CT supply cabling VT supply cabling CT VT Junction box Junction box Meter equipment Data Validation Billing system Miscellaneous meter equipment Meter data capturing Meter pulses Ancillary meter equipment

  42. Accuracy Class Transmission Loads

  43. Metering Data Management System Distributors International REDs Generators • Remote Acquisition of Metering Data • First Line Validation of Data • Limited Storage of Data IPPs Data Acquisition • Second Line Verification & Validation of Data • Data Warehousing • Data Management (Profiling,Totalisation & Mapping) • Reporting • Access Control • Audit Trails Data Management Data Dissemination Customer Application • Transfer of Data to Customer • Stakeholder Systems • Web viewing of metering information

  44. Common Information Model

  45. Why does it cost so much to buy an EMS? Can you take different software packages from one EMS vendor and load them on to a different EMS platform? How can the problem be overcome – two reasons? Common Information Model • You can’t buy shrink wrapped software for SCADA systems • No because every vendor’s data is unique • By agreeing to a standard way of modelling the data interface • Defining a common software interface definition

  46. Overall structure of an EMS Comms link S1 S1 RTU S 2 S 2 S 3 S 3 Scanner Process Control Process Alarm Process Host I/O S 4 S 4 S 5 S 5 S 6 S 6 S 7 S 7 S 8 S 8 Host SCADA Data Base New Process A 1 A 1 Status Record A 2 A 2 Status Record A 3 A 3 Status Record A 4 A 4 Status Record A 5 A 5 Data base Browser Process Analog Record A 6 A 6 Analog Record Analog Record Analog Record ? Status Record 231 234 34 Status Record One Line Display Status Record Status Record Analog Record Analog Record Raw data in the RTU DB Raw data Engineering data

  47. A standard developed by the electric power industry that aims to allow application software to exchange information about the configuration and status of an electrical network. The CIM is currently maintained as a UML model and defines a common vocabulary and basic ontology for aspects of the electric power industry. The central package within the CIM is the 'wires model', which describes the basic components used to transport electricity. Common Information Model S1 S 2 New Process S 3 S 4 S 5 S 6 S 7 S 8 A 1 A 2 A 3 A 4 A 5 A 6 Host SCADA Data Base Status Record Status Record Status Record Status Record Analog Record Analog Record Analog Record Analog Record Status Record Status Record Status Record Status Record Analog Record Integration Bus Analog Record

  48. Purpose • Need a common way to represent the Data to be exchanged – • It is called the CIM or Common Information Model • The CIM is: • a data model defining all relationships • background map for information exchange • CIM is not: • a database (object or relational) • the end of the road

  49. The central package within the CIM is the 'wires model', which describes the basic components used to transport electricity. Common Information Model

  50. Individual application components are interconnected via a component execution system and component adapters. They provide the infrastructure services needed by the components to discover and communicate with each other and with the public data stores in the various EMS contexts. Common Information Model Alarm Topology Network Load Accounting/ Generation Legacy System Processor Processor Applications Management Settlement Control SCADA Programs Programs Programs CIM Server Programs Programs Programs Network Legacy Wrapper Public Data Public Data Public Data Public Data Public Data Public Data Component Execution System and Component Adapters (e.g., Integration Bus) User Distribution PCs Management Public ICCP Public Component Data Systems Data Network Interface Programs Programs ICCP

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