Smart Grid:Electric Utility Scada DMS OMS GIS

Automation Road map International Practices in Utility Automation Presented at PMI Meet 2007 Himadri Banerji CEO Reliance Energy 1

The Utility Industry today survives on integrated Information on Real time Basis 2

Integrated Information from Generation to Load DTPS : Gross Heat Rate (kcal/kWh) DTPS : Daily Load Curve 2340 2320 2300 640 2280 540 2260 440 340 2240 240 1 an -J 5-J an 9-J an 1 an 3-J 1 an 7-J 21 an -J 25-J an 29-J an 0 5 10 15 20 Actual Target Design Generation Demand Capacity BKPL : Net Heat Rate (KCal/KWH) 220 KV Tie line: Load Curve 2200 2100 200 MW 2000 100 1900 0 1 an -J 5-J an 9-J an 1 an 3-J 1 an 7-J 21 an -J 25-J an 29-J an -100 1 3 5 7 9 11 13 15 17 19 21 23 Individual tie line limit Versova Aarey Total Actual Target PPA SPS: Net Heat Rate (Kcal/KWh) SPS: Load Curve 2425 120 2325 115 Heat Rate 2225 110 2125 105 2025 100 1925 95 30-Dec 3-Jan 7-Jan 11-Jan 15-Jan 19-Jan 23-Jan 27-Jan 31-Jan 90 Actual PPA T arget 1:00 3:00 5:00 7:00 9:00 11:00 13:00 15:00 17:00 19:00 21:00 23:00 GOA: Net Heat Rate (Kcal/KWh) GOA : Load curve 2450 48 46 Heat Rate 2300 44 2150 42 40 2000 38 1850 36 34 32 2-Jan 9-Jan 16-Jan 23-Jan 30-Jan 30 Actual Target PPA 0:00 3:00 6:00 9:00 12:00 15:00 18:00 21:00 Utility wide Integrated Information is the key to Decision Support 3

Tomorrow’s Vision Asset Energy Sales Integrated utility management & Customer Care business operation Data warehouse Business Enterprise Bus ... Services Added value network Advanced applications Network Network Meter data (EMS, DMS, Trading) planning information management management & optimization (applications and systems) ... Gateway Network control & SCADA Information DB gateway supervision (single-or multi-utility) IT Integration Communication Private & public networks Multi-site Local Substation Protection RTUs Meters Field data acquisition, automation automation local control & automation xxxx x xxx xxx xx Capability to provide solutions for an integrated utility business operation 4

Today’s Automation Scenario Transmission Generation Highly Automated (Automated SLDC, 42 RTUs, (DCS, Automated S/Y) 210 more planned) Bottleneck is here • Last mile Reliability Distribution • Huge No. of elements (almost nothing) • Almost zero visibility • Feed complexity • Theft • Revenue collection 5

Forward step to Distribution Automation Zone • The proposed implementation strategy balances an ambition to implement a “state-of-the art” SCADA/GIS, with immediate business priorities, time pressures and automation preparedness based on sound DMS fundamentals,delivery experience and visions. Time Pressures Ambition Preparedness Level Benefits Priorities SCADA/DMS integration with GIS will bring IT Revolution into Power Distribution Business 6

Distribution Automation Evolution Present Intermediate Final Phase Monitorin Centralize Centralize g Manual d d Decision Centralize Centralize Manual d d Control Decentralis Decentralis Centralize ed ed d Monitoring, Decision and Control functions can be made centralized in steps 7

Enterprise wide Geographical Information System (GIS) GIS Platform Enterprise Data Management Network Data ArcCatalog, ArcMap ArcSDE, ArcIMS SLDs, Layouts, Cable Routes Equipment Data Structural Data New EHV Stations , Specifications, Diagrams, Towers, Pillars, HVDS, LTMP, Operational History Poles, Plinths O&M etc. Consumer Data Network Analysis Responder OMS, Name, Kno., Service Tools, Application ArcFM Programs Line, DT No Seeing is believing !!!!!!! We have seen it 8

System Architecture Business Customer Transmission/Distribution Support Care (CIS) WMS/Staking/IVR XML XML XML XML Integration Framework ArcFM Solution (Models and Tools for Mapping and Network Data Management) ArcGIS (Core GIS Functions) Other databases Open RDBMS 9

Enterprise Wide Integrated GIS. OMS- Responder Consumer Network Information Analysis System(CIS) GIS-AM/ FM SAP SCADA-DMS Custom Tools ( Energy Audit Scheduler et al.) 10

SCADA/DMS - GIS , a birds’ eye view Geographical info, Schematic diagram availability at central location addresses key operational concerns This ultimately leads to improvement in System Safety, Efficiency and Customer Service (Power Quality and Reliability) 11

DMS - Operations Benefits 11kV SLD Grid SS 66/33kV SLD Window on GIS DMS View 12

DT – bldg – pole – K No. – The governing relationship 13

SUPPORT STRUCTURE WITH ATTRIBUTES 14

CONSUMER DATA 15

Electric Network Trace for 66/33/11 KV Network 16

Load growth planning Using Geo-referenced data 17

Distribution Automation – Implementation Strategy Overview UHBVNL .TASE 2- ICCP Link Sub-SLDC, Narvana MCC Cum BCC ( to Second Discom) and Visa versa For 33 kV, 11 kV Discom Network SLDC, Panipat Synchronized Link NRLDC, Delhi DHBVNL Existing Substations Sub-SLDC, 400 kV- 5 No Dadri 220 kV- 37 No 132 kV- 112 No 66 kV – 95 No 33 kV- 293 No 18

Distribution Automation –Communication Alternative MCC EIT, Haryana OFC Substation Automation OFC OFC Energy meter AMR Communication Link OFC CDMA-LPR CDMA-LPR FSS CDMA-LPR BCC RMU ion To ss on mi i R - DTs LP M A ns mat CD Tra uto A n tio bu tion tri a Dis tom Au LT Consumer Building 19

DMS – Benefit to System Operations – Real-Time Network Monitoring , Control, Visibility and Metering – “As-Operating” diagrams (SLD) with its Spatial Illustration – Control Room Management – Decision support tools to assist • Fault Location, Isolation and Restoration • Load Shedding – Crew Management – Automatic event logs, loading reports and performance statistics All the above achieved in a consistent manner across entire Network – Trouble calls and Outage management and business enterprise with one Central System backing up the two Discoms 20

Stepwise Approach for Distribution Automation Phase I- GSS Automation upto 11 kV CB Phase IA- 11 kV Connectivity Modeling Control Phase II- Automation of FSS& center Substation High Level DMS Applications automation Phase III- Automation of Selected Normal Operating Points, RMU’s 33 kV Phase IV- TCM ( SCADA Centric) 11 kV AMR- Key Consumers HTC Transmission automation FSS SIP FSS LIP Control center Res. Distribution automation SCADA – DMS – Feeder Automation 21

Existing System and Automation Benefits 22

11 kV network – Existing Operations R/S feeder Switching Station & Circuit Breaker R/S feeder Distribution Transformer Normally open point Second feed available through First Switching station 23

11 kV network – Existing Operations R/S feeder Switching Station R/S feeder Distribution Transformer Normally open point 24

11 kV network – Existing Operations R/S feeder Switching Station & Circuit Breaker R/S feeder Distribution Transformer Normally open point Receiving Station breakers clears the downstream fault, 50% consumers affected 25

11 kV network – Existing Operations Switching Station & Circuit Breaker R/S feeder R/S feeder Restoration takes more time due Limitation on cable size & non availability of RMU Distribution Transformer Normally open point Supply restored manually for part of network typically in 2 hrs 26

11 kV network – Existing Operations R/S feeder Switching Station & Circuit Breaker R/S feeder Distribution Transformer Normally open point Restoration of supply manually  additional 2 hr -> total 4 hrs 27

11 kV network – Automated Operations: Advantages R/S feeder R/S feeder Circuit Breaker Total number of consumers affected due to 11 kV outage will reduce by 75 % RMU / DT Normally open point Fault Restoration time can be reduced to 20 Minutes from existing 4 hrs 28

Advantages: Faster Fault Location, Isolation and System Restoration System wide Consistent Network Status and Performance Grid Substation Remote Control of all switching devices Automation Dynamic Network Coloring and Job Management Operators Load flow, Volt/VAR Control Load Shedding, Load Forecasting Outage Management ,better tracking of Manual Operations Consistent Network status & performance Monitoring 11 kV Network & Optimal Switch Management Feeder Automation Network Flexibility 1-2 % reduction in Technical Losses can be achieved by Crew management Optimal Network Configuration Contingency Management Overall improvement in System Safety, Efficiency and Customer 29 Service (Power Quality and Reliability)

Key Preparedness Issues- First Step Towards Automation Existing System Audit Issues Action Initiation Primary Equipment Grid Substation Level SCADA Adaptation Compatibility with SCADA 11 kV Switching Devices Rehabilitation inline with Generally Unreliable (FSWS,SSWS, RMU) DMS Implementation Network Diagram and Data Non availability of Base Network Modeling , (Upstream and downstream Drawings and data Optimal RMU & Network) Upto 11 kV network Automation Points Study Acknowledge the “Need to Change” 30

Summary –Transmission and Automation State may decide to take an integrated view on Long term system planning using “State of art” network study tools, GIS with level of automation considering following alternatives : Upgrading STU network to 400 kV level Additional 220 KV Lines and Substations in line with load growth Upgrading • Existing 132 kV to 220 KV • Existing 33 kV to 66 kV Adopting International Planning Practices like • N -1 Contingency • Reliability and Availability Criteria Adopting “State of Art” emerging technologies in Transmission SCADA and Extension to DMS and Feeder Automation ( Stepwise Approach) Keeping in view of large scale development plans and load growth in the state, Transmission network backbone needs planning using International “Bench Mark” Practices and State of Art Technologies 31 This will lead state to comply with international norms on Reliability and Availability

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Smart Grid:Electric Utility Scada DMS OMS GIS

by HIMADRI BANERJI

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