power system scada part ii (ems,dms)sasidharan.webs.com/documents/scada part ii.pdf · power system...
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Power System SCADA – Part II
(EMS,DMS)
Dr. Sasidharan Sreedharan
www.sasidharan.webs.com
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Contents
Energy Management System (EMS)
• AGC
• Energy Pricing (ABT)
Distribution Management System(DMS)
• Distribution Automation
• SS Automation
Case Studies (SCADA With Distribution Automation)
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Syllabus Update
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SCADA/EMS Architecture
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SCADA/EMS/DMS Architecture
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EMS/DMS Functions
EMS
• Network Configuration / Topology
Processor
• State Estimation
• Contingency Analysis
• Three Phase Balanced Power Flow
• Optimal Power Flow
DMS
Voltage Reduction
Load Management
Power Factor Control
Two‐Way Distribution Communications
Short‐Term Load Forecasting
Fault Identification / Fault Isolation / Service
Restoration
Interface to Intelligent Electronic Devices (IEDs)
Load Forecast : Every hour for a period of 1-7 days
LFC : Every few seconds
• ED : Every few minutes .
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EMS Detailed Function • System load forecast :
• Unit Commitment : Start up & shut down times for most economic operation of thermal units for each hour.
• Fuel Scheduling : Economic choice, fuel purchase contracts.
• Transaction evaluation : Purchase & sale of energy with neighboring companies.
• Transmission loss minimization : Controller actions for minimization of loss.
• Security constrained dispatch : Ensuring eco dispatch without violating network security.
• Production cost calculation : Actual & economical for each generated unit on hourly basis.
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Power System Action Time Frames
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Grid Management
• Unit commitment – which works on a scale of days
• Scheduling needed on a day upon day basis
• Load following which has a time scale of minutes to hours
• Regulation which happen over seconds to minutes
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Load Dispatch Centre - Functions
Load Generation Balance(LGB) preparation
Demand Forecasting
Scheduling of Central share
Power Purchase
Outage Planning
Preparation of Daily System Statistics
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Load Generation Balance (LGB)
Ensuring availability of generation to meet the ever-changing demand in the most optimal way
• Real time
– The actual demand has to be met with power availability
• Long term (Control period)
– Energy requirement for the control period is to be met
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• Stable and Secure grid operation
• Effective utilization of available resources
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Factors affecting LGB
Major loss of generation / Central grid station (CGS)
outage
Transmission line outage
Climatic condition
Price signal from power market
Spill threat
Conservation requirement
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Preparation of LGB
Factors considered
1. Demand forecast
2. Generation schedule
– KSEB
» Hydel
» Thermal
– IPPs
3. Availability of CGS Share
4. Power Purchase AIT/SCADA - Day 4 15
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Demand Forecast
Forecast to be made for day ahead demand and
energy requirement.
Demand forecast is divided into segments like
• Night-off peak (22:00hr to 05:00hr)
• Morning peak (05:00hr to 08:00hr)
• Day peak (08:00hr to 18:00hr)
• Evening peak (18:00hr to 22:00hr)
Availability to be ensured for each segments AIT/SCADA - Day 4 16
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Factors affecting demand
• Climatic condition
• Festivals
• Major holidays
• Major sports events and Political developments
• Social disturbances and strikes
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Typical Demand Curve
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Power Purchase
Power is purchased from
i. Central Electricity Regulatory Commission
approved Traders and
ii. Power Exchanges
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Availability Based Tariff
• Introduced in Southern Region with effect from 1-1-2003
• Tariff promotes grid discipline with its inherent commercial mechanism
• Consists of three parts: Fixed charge or Capacity charge
Variable charge or Energy charge
UI (Unscheduled Interchange) charge
www.srldc.org
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Tariff Structure
• ABT is a three part tariff
–Capacity charges (Fixed cost)
–Energy charges (Variable cost)
–UI charges
Capacity charges and energy charges are settled monthly as per the Regional energy Account.
UI charges are settled weekly
Energy accounts are prepared and issued by the Southern Regional Power Committee Secretariat
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Major problems existed in grid operation prior to the implementation of ABT
• Low frequency during peak load hours - 48.0-48.5 Hz
• High frequency during off peak hours - 50.5 to 51 Hz
• Rapid and wide changes in frequency – 1 Hz in 5 to 10 minutes.
• Very frequent grid disturbances, causing tripping of generating stations, interruption of supply to large blocks of consumers, and disintegration of the regional grids.
One important reason attributed to the situation was the absence of direct incentives or penalties for the individual
utilities responsible for the problems.
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Beneficiary UI
Actual drawal by beneficiary
Drawal Schedule by RLDC
+UI
-UI
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What is UI?
UI – Unscheduled interchange Demand of the grid is not constant Frequency of the grid is not constant Depending on various conditions, the tie line flow
varies from instant to instant Thus UI is unavoidable in an integrated network UI can be harnessed effectively to the advantage
of the constituents if system permits The UI is the difference between the schedule
and the actual draw up / generation. Rate depends on frequency CERC finalizes Inter state UI rate
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UI Rate
0
50
100
150
200
250
300
350
400
450
48.50 49.00 49.50 50.00 50.50
Frequency (Hz)
UI R
ate
(P
ais
e/U
nit
)
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VAR Rates
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VAR injection at Voltages above 103% of rated voltage VAR drawal at Voltages below 97% of rated voltage
VAR drawal at Voltages above 103% of rated voltage VAR injection at Voltages below 97% of rated voltage
Payable @10 ps/KVARH For
.
.
Receivable @10 ps/KVARH For
.
.
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ADVANTAGE ABT.
• MAXIMISATION OF GENERATION AVAILABILITY – MEET MORE CONSUMER DEMAND
• ECONOMY IN OPERATION – REDUCE COSTS
• RESULT :- – IMPROVED QUALITY OF SUPPLY.
– UNUTILISED CAPACITY HARNESSED.
– MERIT ORDER IN GENERATION.
– GRID DISCIPLINE
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SUB STATION AUTOMATION Why Needed?
Why Now? DEREGULATION & COMPETITION Deregulation driving actions of most utilities Major driving forces: • Improved power quality and service reliability • New energy related services and business areas • Lower cost of service • Information needed for improved decision making
SA: A proactive response to these forces
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Why Needed? Why Now?
DEVELOPMENT OF IEDs Rapid development and deployment of Intelligent Electronic Devices (IEDs) • Protective relays • Meters • Equipment condition monitors IEDs have become an integral part of Substation Automation systems Technological developments have made SA systems less expensive and more powerful
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Automatic Load Restoration: “Intelligent” Bus Failover
• Nature of Problem – When a transformer failure occurs, “simple” bus
failover scheme transfers load to healthy transformer
– “Simple” failover scheme may overload healthy transformer, especially during peak load
– Some schemes have been disabled because of this.
– Substation firm capacity limited by amount of load that can be carried if a transformer fault occurs.
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Automatic Load Restoration: “Intelligent” Bus Failover
• Objectives – Transfer as much load as possible to 2nd
substation transformer
– If necessary, transfer portion of load to alternate substation
– Shed portion of load if necessary
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“Intelligent” Bus Failover:
How It Works
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Transformer
Fault
Occurs
“Intelligent” Bus Failover:
How It Works
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Trf
Protection
Operates
“Intelligent” Bus Failover:
How It Works
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Bus Transfer
Scheme
Operates
“Intelligent” Bus Failover:
How It Works
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Shed Load
If Necessary
To Adjacent
Substation
“Intelligent” Bus Failover:
How It Works
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Restore Load
Using Feeder
Automation
To Adjacent
Substation
“Intelligent” Bus Failover:
How It Works
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Supply Line Sectionalizing
42
SA
System
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Supply Line Sectionalizing
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Permanent
Fault Occurs
SA
System
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Supply Line Sectionalizing
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Line
Protection
Operates
SA
System
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Supply Line Sectionalizing
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Line Protection
Reports Fault
Location
SA
System
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Supply Line Sectionalizing
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SA System Opens
Appropriate device
SA
System
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Supply Line Sectionalizing
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SA System Sends
Reclose Signal
SA
System
AIT/SCADA - Day 4
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Equipment Condition Monitoring • Continuous On-line Diagnosis
of SS Equipment (HV breakers, Transformers)
• Main objectives
– Find/fix problems earlier – Avoid forced (unscheduled) outages – Reduce maintenance costs
• Role of SA
– Monitor specialized sensors – Perform “expert system” analysis – Inform engineers or dispatchers of
possible problems
48 AIT/SCADA - Day 4
• Dissolved Gas in Oil
Monitors/Samples
• Moisture Detectors
• Load Tap Changer Monitors
• Partial Discharge/Acoustic Monitors
• Bushing Monitors
• Circuit Breaker Monitors (GIS and
OCB)
• Battery Monitors
• Expert System Analyzers
Monitoring
Devices
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Adaptive Relaying
• Process of automatically altering settings on protective relay IEDs based on system conditions
• Special Protection Schemes – SA system can play a role in implementing bulk power Special Protection
Schemes (SPS)
– Example: tripping of critical generating unit requires new settings on a line that may become very heavily loaded under this condition.
• Benefit – Avoid need to implement custom hardwired logic to
accomplish this functionality 49
Critical
generating
unit trips
EMS
detects
unit trip
EMS
informs
SA system
of the
event
SA System
switches line
relay to new
settings
AIT/SCADA - Day 4
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Intelligent Alarm Processing
– Prioritize alarm information
– Eliminate duplicate & nuisance alarms
– Route alarm info to appropriate party
– “Expert” alarm processing
• provides more informative and useful alarm messages
50 AIT/SCADA - Day 4
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Power Quality Monitoring
– SA System and IEDs able to detect power quality events and report the following information:
• Harmonic content of the voltage waveform
• Total harmonic distortion
• Oscillographic data (waveforms)
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Real-Time Equipment Rating
– Base equipment ratings on actual conditions rather than conservative assumptions
– Squeeze more capacity out of existing equipment
– Example: Transformer “Hot Spot” Monitoring
• Monitor the true winding hot spot temperature
• Derive loadability from the results
• 10% average additional loading can be achieved
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Support for Feeder Automation
SA is an “Enabling Technology” for Feeder Automation functions Integrated volt VAR control
Feeder reconfiguration
Requirements for Feeder Automation: Monitoring of 3 phase quantities at substation end of
feeder
Load Tap Changer set point control
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Monitoring of Switched Feeder Capacitor Banks
– Switched feeder cap banks forced out due to blown fuses, mechanical control failure, etc.
• 20% failure at one utility
– Banks out of service months before
being discovered
– VAR flow monitoring quickly detects
failed cap banks
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Integrated Protection Functions
• Objective:
Incorporate protection functions in the SA System – Basic protection units (IEDs) exchange current/voltage
data via high speed LAN
– Relay trip signals exchanged over LAN
• Examples: – Automatic reclosing
– Breaker failure
– Bus differential
• Benefit: – Avoid cost of separate protective relays
– Potential for improved performance and reliability
55 AIT/SCADA - Day 4
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Hyderabad Integrated SCADA Project
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• The Hyderabad SCADA project involves networking of all the
substations in and around Hyderabad city for.,
Data collection from all substation equipment to the central
Computer system for analysis .,
Control and monitoring of the distribution system by
issuing commands to the remote stations
• The Electricity Distribution system for Hyderabad city spans over
an area of 1555 sq km.
• Over one million consumers are served by APCPDCL
• The system covers 13 nos.132 / 33 kV stations and
93 nos. 33/11 kV stations
Project Synopsis
AIT/SCADA - Day 4 57
APCPDCL: Andhra Pradesh Central Power Distribution Company Ltd http://www.apcentralpower.com/
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• Aim of the Project - Effective Load Management of
Distribution system in Hyderabad to improve the reliability
of the electricity supplies
• SCADA (Supervisory Control & Data Acquisition System) is
integrated with Distribution Automation Functionalities for better
utilization
• Load Control
• Automatic Meter Reading
• Emergency Load Shedding
• Integrated Volt/Var Control
• Feeder SCADA-Fault Localization
• Trouble Call Management
• Facilities Management
AIT/SCADA - Day 4 58
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• Efficient Distribution Management
• Fault analysis easier and quicker due to availability of real time
information
• Prompt and quicker restoration of supply in case of outages
• Malfunctioning equipment can be identified and action can be taken for
rectifying the same early
• Historical data up to a period of 2 years can be stored for future analysis
• Stations can be operated as unmanned substation
• Close monitoring of supply status for essential services and VIP functions
• Load shedding can be programmed in a systematic manner during
shortages or exigencies
AIT/SCADA - Day 4 59
Project Benefits
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Project Finance
• Project is financed by DFID under AP Energy Efficiency
Project (APEEP)
• DFID has so far released Rs 32 crores ( 4.8 million
UKP ) for this project
AIT/SCADA - Day 4 60
Department For International Development (DFID)
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System Details
The Hyderabad SCADA system comprises of the following
subsystems
• Control Center Equipment (Computer System )
• Application Software - SCADA
• Distribution Management Functions Software
• Microwave Communication system
• Field data Acquisition system (Remote Terminal Unit)
• UPS, Power Supplies, Towers etc.,
AIT/SCADA - Day 4 61
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MAR Network
MAR Remote station
R C Puram 132kV
Gachibowli 220kV
TDMA Freq 1
(2.385/2.479 GHz)
TDMA Freq 2
(2.371/2.463 GHz)
Gummadidala 132kV
Medchal 132kV
Bolarum132kV
Jubilee Hills 132kV
Erragadda DCC
Shapurnagar 220kV
Vidyut Soudha
Gunrock132kV
Asifnagar 132kV
Sivaramapalli 132kV
Imlibum 132kV Bandlaguda 132kV
Moulali 220kV
H. sagar 132kv
Chilakalaguda 132kV
Legend:
TDMA Freq.3
2.343 / 2.437
TDMA Central Station
TDMA Repeater
Station
TDMA Outstation
Communication Network
Chandrayangutta 220kV
AIT/SCADA - Day 4 63
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Communication Towers
AIT/SCADA - Day 4 64
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AIT/SCADA - Day 4 65
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AIT/SCADA - Day 4 66
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AIT/SCADA - Day 4 67
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AIT/SCADA - Day 4 68
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AIT/SCADA - Day 4 69
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Historical Data Processing
Long term archiving
Archiving features: - Cyclic or time of day
- Data with quality codes
- Successive mean value calculation
- Backup value
Future
Past Real time
data
Avanti DBMS
Archiving Time
tagge
d
data
AIT/SCADA - Day 4 70
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Historical Data Presentation
. . . . Value A
123.4
121.8
123.6
122.9
Value B
47.4
46.8
48.2
47.4
Value C
186.0
185.2
186.3
185.9
Value X
356.8
353.8
358.2
356.4
Actual
Minimum
Maximum
Average
Time: 01.00
Time: 02.00
Time: 03.00
Time: 04.00
Time: 05.00
Time: 06.00
. . . .
. . . .
. . . .
. . . .
1252 123 123 123 123 123 123 123 123 123
123
123
123
123
123
123
123
123 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfj lkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdf lkdf lkdgfk
Station A
B8 B9
C1 T1 T2
B1 B2
B3 B4 B5 B6 C7
C2
B7
Time tagged data
p min
p max
kW
p
0 6 12 18 h To=24
Duration curves
Curves
Single line diagram
Plans
Reports
10.25.32
AIT/SCADA - Day 4 71
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Spread sheet integration
Future
Past Real
time
data
Avanti DBMS
Time
tagge
d
data
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldgg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg
93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkl 93-04-21 09:36 kjdfjdfsjdfskjdfjdfsjdfjlkfgfdg lkdfnglkjdffjgkdfklgjlkfjglklfdlkdflkdflkdgfklklkldg
Quality code
inheritance
Commercial
spread sheet
• Tables
• Histograms
• Pie charts
• Three dimensional
diagrams
Spread
sheet
interaction
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Disturbance Data Archiving - Post Mortem Review
14:23.00
14.23.10
14.23.30
14.23.40
14.23.50
123.4
123.5
123.6
123.9
122.0
121.8
.
47.4
47.4
47.7
47.9
47.0
46.8
.
186.0
186.0
186.0
185.7
185.7
185.2
.
14.23.20
Value A Value B Value C
1252 123 123 123 123 123 123 123 123 123 123 123 123 123 123
123
123
123
123
123
123
123
123
123
123
123
123
RTU
Storing
Storing
Archive
Master Station
Presentation
Triggering
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New Customer
Accounting Billing
Revenue
Collection
LT Billing HT Billing
e-Seva
ERO-Offices
Web enabled
Collections
(Online Collections)
Common Billing System
e-Seva
Citi Bank
Online
e-Collection
on Box
Credit
Cards
Electronic
Clearing
System aponline
ATMs of
Banks
KIOSKS
of Banks
Payment Through
Telephone
(IVRS) AIT/SCADA - Day 4 74
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Dr. Sasidharan Sreedharan
YBL Systems and Solutions
(Electrical Power System Research Consultants)
www.sasidharan.webs.com
Regards,
75 AIT/SCADA - Day 4