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CERC’sIndian Electricity Grid Code
Regulations, 2010By
Ravi KumarRavi PohaniRavi Rawat
Background
faultsharmonics Varying loads
Different generators
Timeline
March 99- planned by CTU
Jan 2000- approved by CEA
Feb 2000- Enforced
Feb 2002- Revised
April 2006- RevisedApril 2010- Revised
2006, 2008, 2009- Amended
Where does it come from?Electricity Act 2003
Section 79-(1)-(h)
Section 178-(2)-
(g)
Indian Electricity grid code
OBJECTIVES
Technical rules
Commercial rules
For all U
tilities connecte
d to or using ISTS
What’s its purpose?
rulesguidelines
standards
planning development maintenanceoperations
Power System (national and regional grids)
secure reliable
economic efficient
Competition in generation, supply, tradingBy defining a common basis for ISTS operations
forof
in
and
The way it goes
Roles and linkages between various
organizations
Planning code for ISTS
Conditions for connection• Procedure for
connecting to ISTS• Site Responsibility and
schedule
Operating Code for Regional Grids• Operating Policy• System Security
aspects• Demand estimation
and management• Periodic Reports• Outage Planning• Operational Liaison• Recovery Procedures• Event Information
Scheduling and Dispatch Code• Procedure for
scheduling ISGS• Complementary
Commercial Mechanism
• Modality of Flow Information between ISGS and load dispatch centers and other regional entities
Miscellaneous
ROLES OF VARIOUS ORGANIZATIONS (NLDC)
[section 26 (2) of Electricity Act 2003]
Supervising RLDC operationsMonitoring grid operations & security Giving operational feedback for the
proper functioning of national grid
Scheduling and dispatching of inter state electric transmission Coordinating with RLDC
For economic and reliable operations of Grid
Coordinating for international power exchange Levying fee for all such operations
ROLES OF VARIOUS ORGANIZATIONS (RLDC)
[ section 28 & 29 of Electricity Act 2003]
Control of ISGS scheduling Metering & data collectionInter-state Powertransmission
Operation of Ancillary Services and Operation of DSM pool account Reactive power account
ROLES OF VARIOUS ORGANIZATIONS (RPC)
[sec.29(4) sec.38(2.b) sec.39(2.b) of Electricity Act 2003]
Facilitate all functions of planning• Of inter-state/ intrastate transmission
system with CTU/STU• Monthly maintenance of generators &
transmission system• Operational & protection studies for
stable operation of the grid
Reviews reactive power compensation requirement and devices
Evolve consensus on performance and commercial issues of operation of the grid
ROLES OF VARIOUS ORGANIZATIONS (CTU)[sec. 38 of Electricity Act 2003]
Transmission of electricity through inter-state transmission system
Provide non-discriminatory open access
smooth flow of electricity from generating stations to the load centers between different states
Discharge all functions of planning and co-ordination ISTS with STU, central government, state governments, generating companies, regional power committees, CEA, licensees
ROLES OF VARIOUS ORGANIZATIONS (CEA)[sec.73 of Electricity Act 2003]
• National Electricity Plan in accordance with National Electricity Policy (in every 5 Years)
• Make short-term and perspective plans and specify/carry out• Technical standards for construction of electrical plants, electric
lines and connectivity to grid • Safety requirements for construction, operation and
maintenance of electrical plants and electric lines• Grid standards• Conditions for installation of meters • Promote & assist in achieving schemes and plans in time• Collection and recording of data• Feasibility and Performance studies• Carries out Investigations for purposes of generating or
transmitting or distributing electricity
ROLES OF VARIOUS ORGANIZATIONS (STU)[sec.39 of Electricity Act 2003]
• Undertake transmission of electricity through intra-state transmission system
• Discharge all functions of planning and co-ordination for • intra-state transmission system with CTU, state government,
generating companies, regional power committees, CEA & licensees
• Ensure smooth flow of electricity from generating stations to the load centers within the states
• Provide non-discriminatory open access
• Operate SLDC
secure
reliableeconomic
efficient
ROLES OF VARIOUS ORGANIZATIONS (SLDC)[section 32 of Electricity Act 2003]
• Permitting Open Access• Scheduling drawal from ISGS• Regulating net drawal• Demand Estimation in coordination with STU/DISCOM• Demand Regulation• Scheduling and dispatching
Planning Code• Objective: specifies principles and procedures for inter-state and inter-
regional planning and development; promotes coordination amongst regional constituents by providing methodology and information exchange
• Scope:• CTU• Transmission Licensee• ISGS• IPPs• SEBs• STUs• Licensees for transmission and generation
• CEA – transmission plan• CTU – plan system strengthening, taking advice from RPC CEA RLDC and
beneficiaries• CTU- nodal agency for long term transmission access• RLDC- for short term open access• Withstanding capacity of ISTS against- line and transformer outage• All generating units should work within the reactive power limits• Any one of these events defined above shall not cause:
• Loss of supply• Prolonged operation of the system frequency below and above specified
limits.• Unacceptable high or low voltage• System instability• Unacceptable overloading of ISTS elements.
Connection Code• CERC- grants connectivity for Long term and medium term open
access (abiding to grid standards by CEA)• Things to be taken care of while seeking connection:
• Reactive Power Compensation• Data and Communication Facilities• System Recording Instruments• Responsibilities for safety• Cyber Security• International connections to ISTS• Schedule of assets of Regional Grid
Operating Code
• System Security Aspects• Deliberate isolation of ISTS equipment not permitted• Operation of generating units in “RESTRICTED GOVERNOR MODE” and also
automatic voltage control• Sudden bulk change in generation and loading not permitted• Frequency band tightened from 49.9-50.05 Hz
Scheduling and dispatch code• It specifies:
• Responsibilities of SLDC and NLDC – different control areas – with different controllers- for balancing frequency of synchronously operating system- by controlling generation and maintain interchange schedule
• Procedure for scheduling and dispatch – foreseen MW cap of plant * state’s share in that capacity; (rest show in diagram)
• Reactive Power Control Mechanism-The Beneficiary pays for VAr drawal when voltage at the metering point is below 97% or above 103 % and is paid when VAr returned when voltage is below 97% and above 103% before metering point
• Voltage Control Mechanism• Commercial Mechanism
Control Area Concept
Scheduling Procedure
ISGS
RLDC8 10 15 18 22 23
SLDC
17
Station wise MW/MWh capacity
State wise MW/MWh entitlements
SLDC reviews own load forecasts and own generating schedules
PX file fromNLDC
Net drawal schedule
Power Plant dispatch schedule
Revision
Revision
Dispatch schedule for next day
Drawal Schedule
for next day
Collective Scheduling Procedure
NLDC11 13 14 16 17 17:30
Exchanges
RLDC final schedule for regional entities by 1800hrs
15
list of interfaces/control areas/ regional transmission systems on which unconstrained flows are required
total drawal and injection in each of the regions
period of congestion & available limit for scheduling
Scheduling Request of Collective Transaction
confirm acceptance
Application for Scheduling
interchange on various interfaces/control areas/regional transmission systems
confirm acceptance
Examples of GRID Indiscipline
Switching off of ISTS element without permission of RLDC (except under emergency)
inadequately qualified & untrained trained personnelIn control centers
Deliberately isolating part of the grid from the rest of the regional grid
suddenly reducing generating unit output by more than one hundred (100) MW (20 MW in case of North-Eastern region)
Sudden increase in load by more than one hundred (100 MW) (20 MW in case of North-Eastern region)
Not ensuring/ providing of RTU and othercommunicationequipment for sendingreal-time data to SLDC/RLDC at least before date of commercial operation of the generating stations or sub-station/line being connected to ISTS
Protection systems unable to isolate the faulty equipment within the specified fault clearance time with reliability, selectivity and sensitivity
CONCLUSIO
N