At B.S.E.S(Rajdhani.) ,NewDelhi
TABLE OF CONTENTS PARTICULARS CERTIFICATE PREFACE ACKNOWLEDGEMENT
PAGE NO.
Submitted By: SAJAL KRISHN MEDICAPS INSTITUTE OF TECHNOLOGY AND MANAGEMENT, INDORE(M.P.) ENGINEERING
1. ABOUT THE BSES
1
1.1 BSES IN DELHI
1
1.2 OVERVIEW OF DELHI DISTRIBUTION DISTRIBUTION NETWORK
2
1.3 DELHI DISTRIBUTION NETWORK TREE
4
1.4 DRAWBACKS OF OLD DELHI DISTRIBUTION SYSTEM
5
1.5 NEED FOR SCADA
5
2. SCADA
7
2.1 ELEMENTS OF SCADA
7
2.1 .1FIELD LEVEL
7
2.1.2SYSTEM LEVEL (AT CONTROL CABLES)
8
2.2 ADVANTAGES OF SCADA
8
2.3 PROTOCOLS USED IN SCADA
8
3. SCADA ADAPTATION WORK
9
3.1
INTRODUCTION
10
3.2
INPUT/OUTPUT SIGNALS FOR SCADA
12
3.3
ADAPTATION WORK PROGRESS
15
3.4
SCADA PROJECT IMPLEMENTATION IMPLEMENTATION PHASES
16
4. SYSTEM ARCHITECTURE
17
4.1
HARDWARE ARCHITECTURE
18
4.2
SOFTWARE ARCHITECTURE
18
5. SCADA SYSTEM COMPONENT
19
5.2
MAIN CONTROL CENTRE
20
5.2
BACK-UP CONTROL CENTRE
20
5.3
REMOTE TERMINAL UNIT (RTU)
21
5.3.1 INTRODUCTION
22
5.3.2 COMMUNICATION COMMUNICATION RACK
22
1. ABOUT THE BSES
1
1.1 BSES IN DELHI
1
1.2 OVERVIEW OF DELHI DISTRIBUTION DISTRIBUTION NETWORK
2
1.3 DELHI DISTRIBUTION NETWORK TREE
4
1.4 DRAWBACKS OF OLD DELHI DISTRIBUTION SYSTEM
5
1.5 NEED FOR SCADA
5
2. SCADA
7
2.1 ELEMENTS OF SCADA
7
2.1 .1FIELD LEVEL
7
2.1.2SYSTEM LEVEL (AT CONTROL CABLES)
8
2.2 ADVANTAGES OF SCADA
8
2.3 PROTOCOLS USED IN SCADA
8
3. SCADA ADAPTATION WORK
9
3.1
INTRODUCTION
10
3.2
INPUT/OUTPUT SIGNALS FOR SCADA
12
3.3
ADAPTATION WORK PROGRESS
15
3.4
SCADA PROJECT IMPLEMENTATION IMPLEMENTATION PHASES
16
4. SYSTEM ARCHITECTURE
17
4.1
HARDWARE ARCHITECTURE
18
4.2
SOFTWARE ARCHITECTURE
18
5. SCADA SYSTEM COMPONENT
19
5.2
MAIN CONTROL CENTRE
20
5.2
BACK-UP CONTROL CENTRE
20
5.3
REMOTE TERMINAL UNIT (RTU)
21
5.3.1 INTRODUCTION
22
5.3.2 COMMUNICATION COMMUNICATION RACK
22
5.3.3 EXTENSION RACK
23
5.3.4 MFM PANEL
24
5.3.5 RTU COMMUNICATION
25
6. SCADA FUNCTIONS
25
7. SCADA SECTIONS
26
a.
ENGINEERING SECTION
26
b.
CONTROL SECTION
28
c.
COMMUNICATION SECTION
30
8. DISTRIBUTION MANAGEMENT SYSTEM
35
9. GEOGRAPHIC INFORMATION SYSTEM
37
APPENDIX
38
REFERENCES
40
CERTIFICATE
Mr. SAJA SAJAL L KRIS KRISHN HN Of MEDICA MEDICAPS PS INSTIT INSTITUTE UTE OF This his is to cert certif ify y that that Mr. TECHNOLOGY AND MANAGEMENT, INDORE has completed the summer training of four weeks in SCADA at BSES (RELIANCE ENERGY LTD.) and this report is based on the training acquired and the practical knowledge gained on field as well as in the control room, at BSES BSES { Nehru Place Place & Balaji.}
DATE……… GUIDED BY:Mr. ANAND KUMAR (D.G.M., SCADA DEPARTMENT, BSES NEW DELHI)
PREFACE This report is based on the four week industrial training which has been the greatest learning experience of my life so far, as it is full of observation and knowledge of practical world. Most importantly I have been given the exposure to the latest technology in the world of SCADA. This report is the result of four weeks training that I had in BSES (RELIANCE ENERGY LIMITED), New Delhi. Joining BSES as a trainee gave me a solid platform and served as the launch pad of my professional carrier. I whole heartedly thank the company as well as their SCADA team for giving me the opportunities to work on the latest technology and bring out the best in me and developing my talents, not only in the technical field but also in my overall personality. The most important virtue that I gained here is how to work in a team. Co-operating and assisting each other in the department helped me to explore my potential and perform much better.
ACKNOWLEDGEMENT With deep sincerity and immense pleasure, I have completed my summer training at BSES (RELIANCE ENERGY LTD.) in New Delhi. The purpose of summer training is to develop skills of performing work effectively and efficiently. My primary obligation is to authorities of BSES (RELIANCE ENERGY LTD.) , who provided me the platform and opportunity to undergo summer taining During my training many helping hands came across my way and now when I have completed my system work, I would like to acknowledge my sincere and endless gratitude to them. First and foremost I express my deep sense of gratitude to Mr. Anand Kumar (Manager) and Mr. Aditya for there constant advice and valuable time that they have devoted to me for my project. They encouraged me to put forward my best effort towards the completion of this project. I would also like to extend my special thanks to Mr. Om Prakash, Mr. Ritesh, Mr. Toshan, Mr. Tanmay Mal, Mr. Scentil Kumaran, for their support at every step. At last but not the least I am thankful to each and every one who helped me during the course of my training.
1.
ABOUT THE BSES
BSES Limited is India’s premier utility engaged in the generation, transmission, and distribution of electricity. Formerly known as Bombay Suburban Electricity Supply Limited,
it was incorporated on 1 st October 1929, for the distribution of electricity in suburbs of Mumbai, with a pioneering mission to make available uninterrupted , reliable, and quality power to customer and provide value added services for the development of power and infrastructure sectors. BSES was amongst the first utilities in India to adopt computerization in 1967 to meet the increasing workload and to improve services to its customers. BSES are the first to implement SCADA-DMS systems in India with capabilities at par with the best cities in the world. Some of these systems are Real Time Load flow studies and loss minimization applications, Automated Load Shedding, first ever successful SCADA- GIS integration in the world, Automated Fault Localization, Isolation & service restoration independent parameters, SCADA-AMR integration and availability based Tariff application.
1.1 BSES IN DELHI
Earlier the electricity transmission and distribution of Delhi was under the Delhi Vidyut Board (DVB) but later it was overtaken by BSES and now we have joint venture of Reliance Energy Ltd. with the government of NCT, Delhi. Now BSES is looking after the proper management and distribution of electricity supply.
BSES is merely a receiver and donor of electricity supply. It receives or purchases electricity supply mainly from five generating stations.
Generating Unit
Generation
Installed Capacity
I.P.
247.5
105
G.T.
282
198
R.P.H.
135
40
Pragati
330
330
BTPS
705
440
It can also utilize some other generating units such as Dadri, Anta, RAPP, Singrauli etc. according to the consumer demands.
1.2 OVERVIEW OF DELHI DISTRIBUTION NETWORK It has mainly two parts:
BSES Rajdhani Power Limited
Covers South and West regions
• • • • • • • • •
• • • • • •
Nehru Place Dwarka Jaffarpur Mundka Najafgarh Tagore garden Vikaspuri RK Puram Alaknanda Mehrauli Palam Nangloi Nizamuddin Janakpuri Punjabi Bagh
BSES Yamuna Power Limited
Covers East and Central regions • • •
Yamuna Vihar Krishna Nagar Chandni Chowk
19 divisions 8.61 lacs Consumer
Paharganj Nand Nagri Mayur Vihar • Daryaganj • Jhilmil • Laxminagar • Shankar Road • G.T road • Paharganj • Patelnagar • Karkardoma • •
14 Districts 8.49 lacs Consumer
1.3 DELHI DISTRIBUTION NETWORK TREE Symbolic diagram of Delhi distribution network is shown in above figure. The existing RELIANCE ENERGY distribution network in Delhi is being operated at 66 kV/33kV/11kV and 0.415 kV, with bulk supply at 66 KV/33kV/11kV voltage levels available from TRANSCO. Presently Delhi network is operated sub-optimally and is predominantly manual at a local level based on instructions conveyed from the central location at Balaji Estate through telephone / VHF radios. The decision making at the central location is based on wall mounted static mimic diagrams of the primary network. Globally distribution networks of similar sizes are operated using centralized data acquisition and control with optimized operation of the network based on real time information, improved availability and flexibility with reduced subjective ness. Delhi draws power from 400kV Northern Grid at 400/220kV stations. Delhi’s transmission system at 220 kV consists of twenty-three 220 kV interconnected substations. The powers from these 220/66 & 220/33 kV substations of Transco are fed to RELIANCE ENERGY Delhi area through 20 injection points at 66 & 33 kV voltage level; which are further distributed to 108 substations of BRPL/BYPL . There exist some 11 KV feeds also from TRANSCO to BRPL/BYPL. There are presently 118-grid substations of 66/11 kV, 33/11 kV & 66/33 kV, in addition to this grid stations are also under construction / commissioning and in planning stage. The Primary distribution network operates essentially at 11 kV emanating from the 66 kV and/or 33 kV sub-stations. There are about 1300 numbers of such 11 kV feeders. These 11 kV feeders in turn are feeding to about 8500-Distribution Transformer of 11/0.415 kV.
1.4 DRAWBACKS OF OLD DELHI DISTRIBUTION SYSTEM Existing distribution systems have certain inherent drawbacks. •
The systems are monitored manually.
•
Maintenance taking place only during breakdowns.
•
The present system also does not ensure reliable and complete power system and usage information that can facilitate trend forecasting or help in better analysis and planning.
•
The existing billing systems are still unreliable.
•
The present system has intensive manpower requirement and over-dependence on experts
•
Inaccessible to reach remote locations.
•
Trouble-shooting in case of breakdowns is based on the conventional call system through telephone answering machines.
1.5 NEED FOR SCADA Considering the current operational constraints, a need is felt for visibility of the network on real time basis, flexibility of operational controls, and faster restoration from a central location leading to improved availability of the network. Installation of a SCADA system will lead to following benefits: •
Real time, accurate and consistent information of the System
•
Faster Fault Identification, Fault Isolation and system restoration
•
Extensive reporting & Statistical data archiving
•
Central database and history of all system parameters
•
Improved Availability of System
•
Input for better network planning
•
Optimized operation of the network based on real time calculations.
Implementation of SCADA system will provide supervision and remote control of switches and reclosers such as pole-mounted switches and pole mounted switchgears on high voltage distribution line. This can be remote controlled either automatically or manually, so that it
provide automatic isolation of faulty line sections, which enables quick and accurate recovery of a stable power supply, and also minimizes the out-of service areas by units of distribution sections.
2. SCADA Supervisory Control and Data Acquisition (SCADA) system is a major tool that will be used for improving network operations. SCADA refers to a system that enables an electric utility to remotely monitor, coordinate, control and operate distribution
components, equipment and devices in a real-time mode from remote locations with acquisition of data for analysis, and planning from one central location.
A suitable SCADA system to monitor and control its distribution network is an imperative for optimally running a distribution network, especially for a metropolitan city like Delhi. Distribution automation through SCADA systems directly leads to increased reliability of power for the consumers and lower operating costs for the utility. It results in forecasting accurate demand and supply management; faster restoration of power in case of a downturn and a quick, alternate arrangement for power for important/emergency locations. It puts us in a better position to undertake both active and reactive power management and with better anticipation of trouble and greater trouble-shooting through remote access. Predictive maintenance results in reduced cost of maintenance of power system devices, thereby extending their life. SCADA also reduces human influence and errors. It offers complete power system controls and data acquisitions in a central location, thereby assisting operators in faster decision-making for healthy power supply. It also ensures reliability and quality of power supply (minimum fluctuation in voltage supplies) for the consumers.
2.1 ELEMENTS OF SCADA A typical SCADA system broadly comprises the following elements
2.1.1 FIELD LEVEL At 66/33 kV Grid level: •
Remote terminal units – RTU 560 Type 1-Type 11
•
Multifunctional Meters (MFMs capable of calculating 32 parameters)
•
Intelligent Electronic Devices (Numerical Relays – ER, ABB, Siemens, Alstom)
•
Marshalling Panel, Control Cables
•
CMRs, Digital WTI,OTI,TPI etc
At 11 kV switching sub station •
FRTU 211 – Type 1-Type 8
•
Fault Passage Indicators
•
Motorized RMUs, Battery chargers, Control cables
•
CDMA Modems
2.1.2 SYSTEM LEVEL (AT CONTROL CABLES) •
Front-End Processors
•
Application Servers
•
UDW Servers
•
PDS Server
•
Large Screen Display
•
Operator Panels
•
Firewall & Communication Equipment
2.2 ADVANTAGES OF SCADA • • • • • •
Supervisory control Improved Visibility Data Acquisition SCADA Events SCADA Alarms SCADA Tagging
2.3 PROTOCOLS USED FOR SCADA COMMUNICATION • • •
IEC 60870-5-104 : Communication of RTU to Control Centre IEC 60870-5-103 : Communication of IED to RTU MODBUS : Communication of MFMs to RTU
SCADA ADAPTATION WORK
PRIMARY ADAPTATION WORK 3.1 INTRODUCTION For implementing Distribution Automation and Management System, the primary system components of the 66 / 33 / 11 kV network needs adaptation after which reliable supervision, control and monitoring can be possible. Adaptation considered below refers to SCADA related adaptation. Apart from upgrading of the primary equipment for reliability, there is a need to adapt the installations for remote operation. It is important to consider supplementing the installations with equipment for successful un-manned mode of operation and necessary enhanced safety and security. TATA HONEYWELL is carrying out SCADA Primary Adaptation work for REL. The scope of work includes signal gathering from field / control and relay panels / RTCCP and terminating the connections at a marshalling panel in each Grid station. The scope of work involved can be broadly classified into the following
categories: •
Assessment of existing network elements in the Grid sub stations for SCADA compatibility
•
Generation of Bill of Material based on assessment to ensure SCADA compatibility of the network elements.
•
Supply, Installation, testing and commissioning services for SCADA adaptation of the primary network elements.
Assessment of network elements for SCADA adaptation The scope of work involved under this category includes: •
Identification of Inputs / Outputs required for SCADA from all equipment in the grid stations.
•
Identification and quantification of the spare contacts available from all the network elements either at the switchgear end or from the Control and Relay Panel
•
Identification of the requirement of Contact Multiplying Relays for SCADA inputs.
•
Assessment of extension of secondary of measuring transformers (CT/ PT) to a marshalling panel through transducers / meters in the Control & Relay Panel. 1
The detailed scope involved in assessment for key network elements for SCADA adaptation will be as detailed below.
1. Circuit breakers (66/33/11kV) Indoor and outdoor Circuit breakers are the key elements of distribution system. To implement SCADA there has to be effective signal & command exchange between the remote control center and the circuit breakers. The status monitoring of circuit breaker position will need potential free auxiliary contacts.
2. Isolators (66/33kV) Out door equipment have overhead isolators. These will need to have reliable main and potential free auxiliary contacts for monitoring. It is necessary to ensure that wiring has been extended from these isolators to the control panels.
3. Transformers Grid station Transformers need to be examined for availability of potential free alarm / trip contacts and readiness of tap changer controls. The remote Tap changer control panel has to be adapted for additional control from the control centers. Today these have local at the tap changer, and, remote from local control room. There will be modifications in these panels to enable tap position indication to be sent to SCADA.
4. Measuring Transformers The current and voltage transformers (metering core) are vital elements for analogue information from the installations to control center. The secondary is being extended to marshalling panel or provision of transducers in the Control Panel will be provided for SCADA purposes.
5. Protection systems Availability of auxiliary contacts from the protection relays will be checked for SCADA purposes.
6. Infrastructure for new SCADA equipment 2
It is proposed to implement field wiring from the Control and Relay Panel /RTCCP to a marshalling panel for inputs / outputs required by the SCADA system. New RTU, transducer and communication systems equipment panels will be installed in the station. These will require space, auxiliary, power batteries, additional wiring etc. Space availability & aux power supply for marshalling panel, transducer panel and RTUs and provision of air conditioning for RTUs needs to be ascertained.
3.2 INPUT/OUTPUT SIGNALS The INPUT/OUTPUT signals that are required for the SCADA/DMS are:
CIRCUIT BREAKER •
CRICUIT BREAKER STATUS
•
OPEN
•
CLOSE
•
LOCAL/REMOTE
•
CONTROL
•
OPEN
•
CLOSE
•
ALARMS
•
AUTO TRIP
•
TRIP CIRCUIT HEALTHY
•
TEST POSITION (For indoor switchgears)
•
SERVICE POSITION (For indoor switchgears)
•
SPRING CHARGE
•
DC SUPPLY HEALTHY
•
TIME LAPSE (For capacitor feeders)
ISOLATORS 3
•
ISOLATOR STATUS
•
OPEN
•
MAIN SWITCH
•
EARTH SWITCH
•
CLOSE
•
MAIN SWITCH
•
EARTH SWITCH
TRANSFORMERS •
CONTROL
•
TAP RAISE
•
TAP LOWER
•
STATUS
•
RTCCP LOCAL/REMOTE (SCADA)
•
STATUS
•
OLTC MANUAL/AUTOMATIC
•
CONTROL STATUS
•
ANALOGUE PARAMETERS
•
WINDING TEMPERATURE
•
OIL TEMPERATURE
•
TAP POSITION
•
ALARMS
•
BUCHHOLZ ALARMS
•
BUCHHOLZ TRIP
•
OIL TEMP ALARM
•
OIL TEMP TRIP
•
WINDING TEMP ALARM
•
WINDING TEMP TRIP
•
OLTC SUPPLY UNHEALTHY
•
OIL LEVEL LOW 4
•
PRESSURE RELIEF TRIP
•
MAIN FAN FAILURE
•
OVER VOLTAGE
•
UNDER VOLTAGE
•
TAP CHANGE UNCOMPLETE
•
TAP CHANGE OUT OF STEP
•
TAP CHANGE PROTECTION
•
TAP CHANGE SUPPLY FAIL
PROTECTION SYSTEM •
MASTER TRIP RELAY OPERATED
•
OVER CURRENT & E/F RELAY OPERATED
•
OVER VOLTAGE /UNDER VOLTAGE/NEUTRL UNBALANCE
•
TRIP CKT SUPERVISION
•
VT FUSE FAILURE (LINE SIDE/BUS SIDE)
•
LINE PROTECTION OPERATED
•
AUTO RECLOSURE RELAY OPERATED
•
AUTO RECLOSURE LOCKOUT OPERATED
•
DIFF PROTECTION OPERATED
•
REF PROTECTION OPERATED
•
TRAFO BACK UP PROTECTION OPERATED
•
VOLTAGE UNBALANCE RELAY OPERATED
AUXILLARY SYSTEM AUXILLIARIES •
STATUS
•
BATTERY CHARGER 1 FAIL
•
BATTERY CHARGER 2 FAIL
•
LOAD ON BATTERY 1 5
•
LOAD ON BATTERY 2
•
ANALOG
•
BATTERY 1 VOLTAGE
•
BATTERY 2 VOLTAGE
•
CHARGER1 CURRENT
•
CHARGER 2 CURRENT
•
CHARGER1 VOLTAGE
•
CHARGER 2 VOLTAGE
3.3 SCADA ADAPTATION WORK PROGRESS THL has done the survey of all the grid stations under REL and submitted the survey report to the REL. The survey report includes the single line diagram (SLD’s) of all the grid stations along with the grid station outline showing the space for the marshalling panel and the remote terminal units (RTU). The areas looked upon for making SLD’s are:•
Connectivity details – incomer and outgoing feeder details from grid station (66/33 KV)
•
Bus - 66/33/11KV buses
•
Bus section – 66/33/11KV bus sections
•
Power transformers- rating (MVA), voltage of primary and secondary (66/11KV, 33/11KV, 66/33KV), make
•
Isolators
•
Breakers- type, make, rating
•
CT/PT-rating, type, location
•
11 KV feeders- outgoing feeders panel details
•
Local transformer for grid station-rating, make
•
Earth switches, LA 6
•
Spares- panels, feeders etc
The survey report also contains the status of the I/O points which are to be taken in the SCADA system. Different codes used to define present status of I/O points in grid stations are: •
Code 2- Potential free contact available
•
Code 3- CMR required space available
•
Code 4- CMR required space not available
•
Code 5- Contact not available in control and relay panel
3.4 PROJECT IMPLEMENTATION PHASES Phase I: Project Engineering 1. 2. 3. 4.
System study and Engineering I/O count analysis Requirement analysis and documentation In depth discussions with final vendors
Phase II: System Setup and Commissioning
2. 3. 4. 5. 6. 7. 8. 9.
Setup of Master control centre and PDS server detailed data engineering of Grid substations Picture Editing and Generation (HMI) for use by SCADA operators Individual site evaluation for 117 grids and equipment up gradation for SCADA compatibility SCADA adaptation and RTU commissioning Integration of Intelligent Electronic Devices (IEDs) with ABB RTU 560 OFC used as a communication link with VSAT as backup link for reliable data transfer Testing of grids from MCC and Punch points liquidation
Phase III: Change Management
1. Re-adaptation of various grid substation due to replacement of existing panels (Panel replacement planned at a later stage) 2. Change management at PDS w.r.t. to Data Engineering and HMI regeneration 3. SCADA adaptation and RTU commissioning 4. Integration of Intelligent Electronic Devices (IEDs) with ABB RTU 560 5. Testing of grids from MCC and Punch points liquidation 6. Training of Engineers from various department 7. GIS SCADA integration
7
Phase IV: DMS Data Engineering and Project Execution
1. 2. 3. 4.
Detailed Data Engineering for circle south and Transco(DTL) 11 kV feeders RMU replacement planning based on ALSTOM study RMU replacement and adaptation at DTL sites. FRTUcommissioning and establishment of communication link using FWP CDMA modems.
4. SYSTEM ARCHITECTURE Keeping in view the size of the distribution network and global utility practices, the SCADA system will have one Master Control Center (MCC) and one Backup Control Center (BCC). The BCC will be in hot standby mode for disaster recovery and will cater to the full operational requirements of the network upon severe contingencies to the MCC. Redundancy will be there at MCC and BCC .
4.1
Hardware
Architecture One distinguishes two basic layers in a SCADA system : the “client layer “ which caters for the man machine interaction and “the data server layer “ which handles most of the process data control activies. The data servers communicate with the dvices in the field through process control activities. The data servers communicate with devices in the field through 8
process controllers. Process controllers, e.g. PLCs, are connected to the data servers either directly or via networks or fieldbuses that are proprietary or non propriety. Data servers are connected to each other and to client stations via an Ethernet LAN.
Dedicate client
client
d server
Data
Data
server
server
4.2 Software Architecture The products are multi-tasking and are based upon a real-time database (RTDB) located in one or more server. Servers are responsible for data acquisition and handling (e.g. poling controllers, alarm checking, calculations, logging and archiving) on a set of parameters, typically those they are connected to. However, it is possible to have dedicated servers for particular tasks, e.g. Historian, data logger, alarm handler.
9
SCADA SYSTEM COMPONENT
5.1 MAIN CONTROL CENTER The MCC is the real-time nucleus of the SCADA/DMS. The MCC will be a highavailability system characterized by high-speed 10
data
collection and presentation functions. The MCC collects, processes, and stores real-time data from the following data sources: •
Remote terminal units (RTUs) or FRTUs located at substations, and other facilities throughout the power system
•
Computer systems connected to a computer network linking the SCADA/DMS with the neighboring utilities
•
Computer systems connected to the Information Systems WAN
The MCC database will be accessible by all other component systems of the SCADA/DMS. All data presented to the SCADA/DMS users, used within the SCADA/DMS, and transmitted to computer systems outside the SCADA/DMS will be derived from the MCC database. MCC will have the redundant LAN.
5.2 BACK-UP CONTROL CENTER A stand-alone BCC, located remotely from the SCADA/DMS in the Backup Operations Center (BOC), will be provided to perform SCADA/DMS functions upon catastrophic loss of the SCADA/DMS. The BCC hardware and software technology will be the same as the SCADA/DMS such that the incremental maintenance costs for hardware, software, database, display, and report updates and training is minimized. The hardware configuration of BCC is: •
SCADA /DMS/ICCP Servers (1 operational and 1 redundant)
•
IS&R Servers (1 operational and 1 redundant)
•
Archival Storage
•
LAN Compatible DVD Drive
•
Operator’s Workstations, 3 VDUs (2 nos)
•
Support Console, 2 VDUs (1 no)
•
Support Console, 1 VDU (1 no)
•
Printers
•
Laser printer A4/A3, B&W (2 no)
•
Color Laser printer, A4/A3 (1 no)
•
LAN and Routers for dual LAN of MCC / MCC 11
•
Switch, 10/100Mb/s, 48 ports + 2 ports 1000BaseT (2 no)
•
WAN Router, 2 Eth., 4 WAN slots (2 no)
•
Front End
•
Redundant Front End for communication with 108 RTUs either on IEC-870-5-101 or IEC-870-5-104 protocol (2 no)
•
Standalone front end for communication with 2155 FRTUs consisting of One Line for 15 RTUs communicating on Dialup Line using IEC-870-5-101or 104 protocol.(1 no)
•
GPS Clock (1 no)
•
Video projection system (VPS) 2x4 modules
(for each module of at least 67"
diagonal for BCC) •
UPS (2X 40KVA UPS with common Ni-Cd battery)
5.3 RTU HARDWARE
12
RTU extension rack
5.3.1 INTRODUCTION Remote Terminal Unit (RTU) is brain of SCADA. It includes Marshaling Panel and Multi Function Meter (MFM). Marshaling panel works as an intermediate link between control & relay panel and RTU. All signals collected from C&R panel are first collected in marshaling panel and then connected to RTU terminal box. All analog signals and signals of transformers are collected in MFM. It can measure upto30 electrical parameters. RTU consists of: •
one communication rack or basic rack
•
some number of extension racks (according to the number of signals number of extension racks can be increased)
•
DC to DC converter (to convert any level DC supply to 50V DC on which RTU works)
•
MCBs
5.3.2 COMMUNICATION RACK: •
Redundant power supply unit (PSU) 13
•
Serial line interface cards (SLI Cards) – The SLI Card acts as an interface between
the RTU and the IEDs (Intelligent Electronic Devices). It continually reads data in and out of the IEDs. These IEDs could either be Numerical Relays present on the CR Panel or an MFM placed on the MFM panel of the RTU It is generally placed in a slot of the Basic Rack. The SLI card has got a provision for communicating with the IEDs through four ports, A, B, 1 and 2. The port A and B are of the RS485 type where 1 and 2 are of the RS232. The SLI card has an MMI port for handling the dialogue between the web browser and the RTU. •
Ethernet card – The ETH card controls the process events and communications with
the Control Centers. It continually reads the data from the Extension Racks, the SLI cards and sends it to the control center. The ETH card has a port “E”, which is used by the RTU to communicate to the Master. The ETH is connected to the Extension Rack through port A or B, called COM A and COM B. It also has an MMI port similar to the one present in the SLI card, for handling the dialogue between the RTU and the web browser. The ETH and the SLI cards communicate with each other through a dedicated communication channel present on the back plane of the Basic Rack.
5.3.3 EXTENSION RACK: The Extension rack is a place, which is used to house the Input/Output Modules of the RTU. Similar to the structure of the Basic Rack, the Extension rack has slots into which the I/O modules can be inserted (unlike CPUs in the case of Basic Rack). The extension rack communicates only with the ETH card of the Basic Rack. In cases where there are more than one extension racks, each communication port of the extension rack is looped with the one succeeding it. As mentioned before, the extension rack is connected to the ETH through port A or B, called COM A and COM B. The I/O or Input/Output modules are located in the Extension rack. The function of the Input Modules is to send the status of the equipment present in the grid station to the MCC. The function of the output modules is to control the status of the equipment from the MCC. Thus, we see that the flow of data, in the case of input modules, is from RTU to MCC and from MCC to RTU in the case of Output modules. The different type of I/O modules used are the
14
DI cards – 23BE21 AI cards – 23AE21
DO cards. – 23BA20
DI Card - The DI cards have 16 channels, which can be used for indications. If one takes a look at the front face of the DI card, one can see 16 LEDs. Each LED indicates a particular status at the field.
AI Card -The AI card on the other hand gives the analog value of the signal. It has 16 channels on which eight signals can be configured. The input to a channel in the AI card is a 4-20ma dc current, which is proportional to the range of the analog value.
It will represent following signals: Oil temperature Winding temperature Tap change position Station battery current station battery voltage
• • • • •
DO Card - The DO card is used to execute commands that are sent from the MCC. As soon
as the DO card gets a command from the MCC, it sends a pulse of 48v dc to the exciting terminals of the contactor. As soon as the contactor gets this pulse it closes its contacts and the command gets executed. There is a contactor dedicated to execute a particular command. MCC
RTU (ETH Card)
DO Card CMR Breaker
5.3.4 MFM PANEL The MFM Panel consists of MFMs. On the Panel cutouts are made pertaining to the size of the MFMs. The MFMs are then inserted into the cutouts and are tightly clamped. As mentioned before, the MFM is an IED and it communicates with the MCC through the SLI card. The MFM has 12 terminals to which connections have to be provided. 2 are for auxiliary supply, 4 are for PT secondary, and 6 are for CT secondary. 15
Apart from these terminals, the MFM has a Communicable port and a port to which a hand held programmable and display unit can be connected. The MFM is an IED that can calculate values once the inputs from the secondary of the CTs and PTs have been given. Each MFM is dedicated to a particular panel, be it, outgoing or incoming. The MFM calculates and displays values on a hand held programming and display unit. These values depend on the programmed primary value corresponding to the CT and PT ratio, pertaining to that feeder. There is a communication port available for each MFM. It uses the RS 485 connection scheme. The communication ports of five MFMs are looped. It is extended to the front face of an SLI card through a cable. A maximum of 32 MFMS can be connected to one single cable. The cable is then terminated at the A and B ports of the SLI cards, using an RJ45 jack. In order to terminate the cable in port 1 and 2 of the SLI card, we have to make use of a converter, which converts the RS 485 into a RS 232 scheme.
5.3.5 RTU COMMUNICATION The RTU’s that will be placed in grid stations will communicate with the Master Control Centre (MCC) and the Backup Control Centre (BCC) using the IEC 60870-5-104 protocols on fiber optics. The communication network should be capable of handling traffic from the RTU’s using this protocol. The IEC 60870-5-104 protocol provides the physical interface as Ethernet interface and communication happens over Ethernet. In view of the need for DMS functionalities, communication planning is based on 512 kbps per Grid Station. As a backup VSAT will be used to communicate with the master control center and back up control center using IEC 60870-5-104 or 101 protocols. The final protocol for VSAT will be decided after the protocol testing is done.
6. SCADA FUNCTIONS The following are the functionalities available in the SCADA/DMS: •
DATA ACQUISITION
•
DATA EXCHANGE
•
DATA PROCESSING
•
TAGGING
•
SUPERVISIORY CONTROL 16
•
SWITCHING ORDERS
•
LOAD SHEDDING AND RESTORATION
•
ENERGY BALANCE
•
INFORMATION STORAGE AND RETRIEVAL
•
DATA ARCHIVING
7. SCADA SECTIONS SCADA has following three sections; 1. Engineering sections 2. Control Section 3. Communication Section
a. ENGINEERING SECTION : There are various software’s which are used to help bring out the real picture of grid in our PCs. These include: 1. Data Engineering (DE) 2. Picture Editor (PED) •
Firstly all the information related to grid and incoming and outgoing feeders are given in DE.
•
The various parameters, indications and measurands are defined.
•
Then in Picture Editor, all information related to particular device is fed.
•
The whole diagram is then published on online server and we get the SLD(Single Line Diagram).
The various other Features included in the software: 1. Digital Alarm: Reports to user about various events occurring in grid like breaker in test, Main DC fail, SCADA enabled.
17
2. Analog Alarm: It gives us information about voltage and current levels in various devices of grid. 3. Events List: •
Gives us the total list of events and their occurrence.
•
It tells the time of occurrence up to seconds.
4. Sequence Lists: •
It gives more detailed lists and the events are also sequenced.
•
Their occurrence time is given up to the limit of milli-seconds.
•
Very much helpful in Trouble Shooting.
According to various system demands, different parameters are indicated. There are a permissible 32 indicators, out of which 8 are indicated here. The various indications are: 1. Trip Circuit healthy 2.
Spring Charged
3. Breaker in service 4. Protection Relay(IRF) 5. Auto Trip 6. VT Fuse 7. Main DC 8. SCADA Control Enabled The various values given by MFM (Multi Function Meter) which is the IED in this case are: 1. R phase Current(A) 2. Y phase Current(A) 3. B phase Current(A) 4. R-Y phase Voltage(V) 5. B-R phase Voltage(V) 6. Y-B phase Voltage(V) 7. Active Power(W) 18
8. Reactive Power(VA) 9. Power Factor 10. Maximum Demand(W)
Single Line Diagram Of Grid Station
Measurand sheet of Grid Station
b. CONTROL SECTION
Software used:Operation and Maintenance System (OMS):
Under this software complains are registered and checked out complains are separately served for South, East and Central circle. A parallel complain of PCR i.e. Police Control Room is also checked out. 19
OMS is a software which not only registers complains but also informs it to the required person keeps a well maintained report about all the incidents. This software registers the following operations: 1. Complain Register. 2. Breakdown. 3. Load Shedding 4. Shutdown 5. Load Recovery 6. GDR entry 7. Status Updating 8. Shutdown Planner Similarly following types of reports are well maintained by this software: 1. Daily System 2. No Current 3. Faulty Cable 4. Power Cut 5. ONMS summary. Thus, this software plays a vital role in scada/dms system in checking out complains. Moreover, different color schemes available specifying the complains E.g.: Green- complain is delayed.
Automatic Load Shedding Applications It is a software available to scada system through which by a single click a feeder can be trapped or restored as per the requirement. If the breaker’s state is not defined than feeders can neither be traped nor be restored and if any command is given than they fall under the category of rejected feeders. After the operation, the software also provides an excel sheet reporting various data about the rejection of feeders. 20
Once the command is given, it will be received by RTU trough d/o cards which ultimately picks up the contactor and results in closing, opening and tripping. If the feeder is not tagged its condition is shown by D/I cards. Two blocks are available for the software: 1. Prio block 2. ALSA block
Prio block: With the aid of this block, feeders can be categorized in any group as per the requirement.
ALSA block: Tripping and restoration commands are given under this block. One of the special features available is rather than changing the whole group, one feeder can be deselected.
c. COMMUNICATION SYSTEM: SCADA which is the acronym for “Supervisory Control And Data Acquisition” needs to communicate with nodes placed at various sites which might be products of different manufacturers. To maintain homogeneity in the sharing of resources and information a definite standard is needed which is provided by basic communication models namely “OSI model of communication”. When networks first came into being, computers could typically communicate only with computers from the same manufacturer. The OSI model was meant to help vendors create interoperable network devices and software in the form of protocols so that different vendor networks could work with each other. Like world peace, it’ll probably never happen completely, but it’s still a great goal. The OSI model is the primary architectural model for networks. It describes how data and network information are communicated from an application on one computer, through the network media, to an application on another computer. The OSI reference model breaks this approach into layers.
The OSI Reference Model 21
One of the greatest functions of the OSI specifications is to assist in data transfer between disparate hosts—meaning, for example, that they enable us to transfer data between a Unix host and a PC or a Mac. The OSI isn’t a physical model, though. Rather, it’s a set of guidelines that application developers can use to create and implement applications that run on a network. It also provides a framework for creating and implementing networking standards, devices, and internetworking schemes. The OSI has seven different layers, divided into two groups. The top three layers define how the applications within the end stations will communicate with each other and with users. The bottom four layers define how data is transmitted end-to-e
FIGURE :-- The seven layers
APPLICATION
• Provides a user interface PRESENTATI ON
• Presents data • Handles processing such as encryption
SESSION
• Keeps different applications’ data separate TRANSPORT
• Provides reliable or unreliable delivery • Performs error correction before retransmit NETWORK
• Provides logical addressing, which routers use f or path determination
DATA LINK 22
• Combines packets into bytes and bytes into frames • Provides access to media using MAC address • Performs error detection not correction
PHYSICAL
•
Moves bits between devices
• Specifies voltage, wire speed, and pin-out of cables
CONNECTIVITY OF GRID STATIONS FOR SCADA OPERATIONS 1. All 117 Grid Stations will be connected to the Central Control Room through any of the three methods: •
Fiber (Metro-Ethernet)
•
LMDS (Wireless)
•
VSAT (as back up and intermediate solution)
2. At the grid site there will be Ethernet Interface on RTU for running 104 protocols. 3. RTU is connected to the switch using a CAT-5 twisted pair cable at the Grid Station on which REL can terminate other nodes and run other applications.The Switch is connected to the Router (CISCO 2611 or CISCO 1700). 4. In case of Fiber site, the Router would directly connect to the metro-Ethernet Africa switch provided by RIC. 5. In case of LMDS Site where metro Ethernet is not available, the RIC will connect using the RIC wireless solution LMDS to the nearest LMDS hub and finally to the MPLS VPN using the RIC Fiber. In this solution Ethernet interface would be provided by the LMDS at the GRID Site. 6. For the Sites on VSAT, the connectivity to the MCC and BCC Site from the Earth Station of VSAT Provider will be provided through the NEHRU PLACE office. 23
7.All the Grid Stations will be connected to MCC and BCC through 512 Kbps dedicated bandwidth upgradeable to 2 Mbps or more on fiber optic. The MCC and BCC will be connected through 2 Mbps dedicated line on fiber optic. Depending upon the future requirement the bandwidth can be upgraded seamlessly. 8. The redundancy with regards to the connectivity to MCC or the BCC would be taken care through the VPN solution centrally from the RIC NOC in DAKC, Mumbai. 9. For intermediate solution on VSAT, 19.2 Kbps provided by the HECL will be used for communication between grid stations and the control centers.
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VSAT ON IEC-104 (Present Scenario)
ARRANGEMENT AT INDIVIDUAL GRID STATIONS
ROUTER
V S A T
IEC 60870 –5 104 on (Ethernet Port) at 19.2kbps
RTU
I D U
By ABB
IEDs
IEDs
IEDs
Field Inputs / Outputs IEC 60870-5-103 / MODBUS
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To service providers Hub By BRPL / BYPL IT Group
COMMUNICATION OF RTU WITH FEP
10 Mb L in k fo ICCP
8. DISTRIBUTION MANAGEMENT SYSTEM A distribution management system is a system of computer-aided tools used by operators of electric distribution networks to monitor, control, and optimize the performance of the distribution system. DMS is an information system developed to provide comprehensive support to a utility company’s distribution area, from planning through to placing in production within facilities and including its operation and maintenance and technical, economical and administrative aspects.
In general it offers functionalities that allow us to 26
•
Receive, recode and consult all customer claims relating to service quality
•
Maintain and consult information on each distribution network component and customer attended
•
Maintain and consult information on work carried out in the network
Purpose of secondary network automation •
Online monitoring of 11kV network to plan resources in most efficient manner
•
Reduce average interruption time of energy supply in the 11 kV network
•
Faster restoration to part of affected consumers by reconfiguring the network
•
Identify important nodes in the network for remote switching operation
DMS Application •
Operations monitoring
•
Fault localization, isolation and System Restoration
•
VAR Control
•
Load Calibration
•
Load flow calculations
•
Distribution Load Forecasting
•
Topology Processor
•
Optimal Feeder Reconfiguration
•
Crew Management
•
Intelligent Alarm Processing Function
•
Intelligent Operations Planning Support Functions
•
Loss optimization and Minimization
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9. GIS SCADA INTEGRATION SCADA is the state of the art system installed in Delhi which helps in monitoring and remotely operating of devices and early and proper detection of faults and further in their rectification. There are lots of information which is captured in SCADA which can be viewed at SCADA control room. The same information is then transferred to the GIS (Geographic Information System) and can be viewed at each asset as mapped in GIS with the SCADA devices. The information is transferred to GIS via different LAN / WAN, Firewall, Protocols, Technology (OPC, ESRI, and ABB-SCADA), different operating systems and different geographic locations to GIS and can be visualized using reliance intranet network via Citrix. The information received helps us in identification and getting the information about the different analog and digital values in their geographic contents. Once the distance relays are installed & operational then even the fault distance can be seen at its geographic distance from the operated device (Circuit Breaker). Analog and digital values can be set to appear on GIS plat form whenever there is a specific change and also within a specified time. The online values are fetched from the SCADA server and have a very small time lag in appearing on GIS platform.
This information is utilized to depict assets affected in case of tripping, and number of consumers affected.
APPENDIX 28
APDRP-ACCELERATED POWER DEVELOPMENT AND REFORM PROGRAMME BCC-BACK UP CONTROL CENTER BRPL-BSES RAJDHANI POWER LIMITED BSES-BOMBAY SUBURBAN ELECTRIC SUPPLY LIMITED BYPL-BSES YAMUNA POWER LIMITED CRP-CONTROL AND RELAY PANEL CT-CURRENT TRANSFORMER CTS-CENTRAL TECHNICAL SERVICES DMS-DISTRIBUTION MANAGEMENT SYSYTEM DNP-DISTRIBUTED NETWORK PROTOCOL DPF-DISTRIBUTION POWER FLOW DTL-DELHI TRANCO LIMITED DSOM-DISTRIBUTION SYSTEM OPERATIONS MODEL FDS-FUNCTIONAL DESIGN SPECIFICATIONS FEP-FRONT END PROCESSORS FISR-FAULT ISOLATION AND RESTORATION FO-FIBER OPTICS FRTU-FEEDER REMOTE TERMINAL UNIT FSS-FIRST SWITCHING STATION GPS-GLOBAL POSITIONING SYSTEM ICCP-INTER CONTROL CENTER COMMUNICATION PROTOCOL IEC-INTERNATIONAL ELECTROTECHNICAL COMMISSION IED-INTELLIGENT ELECTRONICS DEVICES IS&R-INFORMATION STORAGE AND RETREVIAL LAN-LOCAL AREA NETWORK LMDS-LOCAL MULTIPOINT DISTRIBUTION SERVICE MCC-MAIN CONTROL CENTER MMI-MAN MACHINE INTERFACE NOP- NORMAL OPERATING POINT OFR-OPTIMAL FEEDER RECONFIGURATION OMS-OUTAGE MANAGEMENT SYSTEM OLTC-ON LOAD TAP CHANGER PT-POTENTIAL TRANSFORMER PDS-PROGRAM DEVELOPMANT SYSTEM PGCIL-POWER GRID CORPORATION OF INDIA LIMITED REL-RELIANCE ENERGY LIMITED RIC-RELIANCE INFOCOMM RMU-RING MAIN UNIT RTCC-REMOTE TAP CHANGE CONTROL RTU-REMOTE TERMINAL UNIT SCADA-SUPERVISIORY CONTROL AND DATA ACQUISITION SYSTEM 29
SLD-SINGLE LINE DIAGRAM TASE-TELECONTROL APPLICATION SERVICE ELEMENT TCP/IP-TRANSMISSION CONTROL PROTOCOL / INTERNET PROTOCOL UPS-UNINTERRUPTIBLE POWER SUPPLY VDU-VIDEO DISPLAY UNIT VSAT-VERY SMALL APERTURE TERMINAL VPS-VIDEO PROJECTION SYSTEM WAN-WIDE AREA NETWORK
REFERENCES DOCUMENT REFERENCES 1. SCADA/DMS SPECIFICATION MANUAL 2. DOCUMENTS PROVIDED BY REL
WEBSITES 1. www. rel.co.in 2. www.abb.com 3. www.abb.co.in 4. www.iec.ch
5. www.google.com 6. www.wikipedia.com
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