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