1. Indian Electricity Grid Code

2. Contents General Role of various organisations and their linkages
Planning code for Inter State Transmission
Connection Code
Operating Code
Scheduling and Despatch Code
Miscellaneous

3. 1. General

4. Introduction Utilities IEGC Rules Guidelines Standards for ISTS
To plan, develop, operate & maintain National/Regional Grid
connected with / using
Power System
Documentation of the principles which define relationship between various users
Facilitation of optimal operation
Facilitation power markets and ancillary services
Facilitation renewable energy sources

5. Compliance Oversight (1.5)
CERC
RLDC
Report
Repeated
Violation/
Persistent
Non
Compliance
suo-motto
Action
Consensus
RPC
Report issues
not sorted

6. Compliance Oversight (1.5)
CERC
Non Compliance by
NLDC,
RLDC,
SLDC,
RPC
or any other person
Report
by any
person
through
petition
Action 6

7. 2. Role of Various Organizations and their linkages NLDC, RLDC, RPC, CTU, CEA, SLDC & STU

8. Role of NLDC (2.2) NLDC RLDC RPC for regional outage Plan
Economy and Efficiency of National Grid
Monitoring of operations and grid security of National Grid
Restoration of synchronous operation of National Grid
Trans-national exchange of power
Feedback to CEA & CTU for national Grid Planning
Dissemination of information
Levy and collection of fee and charges - CERC
Disse
NLDC
Supervision
Coordinate
RLDC
Supervision & control
Coordinate
RPC for
regional outage Plan
Inter Regional Links
Accounting

9. Role of RLDC (2.3) RLDC Exclusive functions
Real time operation , control & contingency analysis
Generation scheduling/ re-scheduling
Restoration
Metering & data collection
Compiling & furnishing of operation data
Operation of Regional UI pool Account. Reactive energy account and Congestion charge account
Operation of ancillary services
RLDC
Exclusive functions

10. For ST Open Access- Nodal Agency
Role of RLDC (2.3)
RLDC
Functions
optimum scheduling
and despatch of
electricity
Monitor grid operation
Keep accounts of
electricity transmitted
Exercise Supervision
and control over
the ISTS
Real time operations
Apex body for integrated operation
Comply the directions
Directions
SLDC
Central
State
For ST Open Access- Nodal Agency
Licensee
Generating company
Generating station / Sub-stations
any other concerned person 10

11. Role of RPC (2.4 ) RPC Decisions RLDC/SLDC/CTU/
Facilitate the stable and smooth operations of the system
Functions:
regional level operation analysis
facilitate inter-state/inter-regional transfer of power
facilitate planning of inter-state/intrastate transmission system
coordinate maintenance of generating units
coordinate maintenance of transmission system
protection studies
Planning for maintaining proper voltages
Consensus on issues related to economy and efficiency
RLDC/SLDC/CTU/
STU/ Users
Decisions
MS SRPC shall certify Availability of transmission system
Prepare Regional Energy Account, Weekly UI, Reactive & Congestion charge account

12. Role of CTU (2.5) CTU State1 State2 Planning shall operate
to undertake transmission of electricity through ISTS
to ensure development of an efficient, co-ordinated and economical ISTS
Planning
shall operate
RLDC
STU
State Govt.
ISTS lines
State1
RPC
Central
Govt.
Generating
Companies
CTU/to provide non-discriminatory Open Access
Will not engage in trading and generation
For LTOA & MTOA nodal agency
State2
CEA
Licensees

13. (Central Electricity Authority)
Role of CEA (2.6)
CEA
(Central Electricity Authority)
will formulate short-term and perspective plans for transmission system
specify technical standards for construction of electrical plants, electric lines and connectivity to the grid
specify safety requirements for construction, operation and maintenance of electrical plants and electrical lines
specify grid standards for operation and maintenance of transmission lines
specify conditions for SEMs
Promote and assist timely completion of schemes
To collect and record electrical data- cost, efficiency
To carry out investigation ( Electrical system)
Shall Prepare National Electricity Plan (NEP)

14. SLDC – Apex body in a State
Role of SLDC (2.6)
SLDC – Apex body in a State
Ensure compliance
Optimum scheduling and despatch
Monitor grid operations
Keep accounts of electricity transmitted
Activities of Real-time operation
exercise supervision and control
Directions and exercise supervision and control
Licensee,
generating company,
generating station,
sub-station
and any other
concerned person
Power System
State
Directions
RLDC

15. Intra-state transmission system
Role of STU (2.8)
STU
to undertake transmission of electricity through intra-state transmission system
to ensure development of an efficient, co-ordinated and economical intra-state transmission system
Planning
shall operate
SLDC
CTU
State Govt.
Intra-state transmission system
RPC
Generating
Companies
STU/to provide non-discriminatory Open Access
Licensees
CEA 15

16. Role of STU (2.8) STU Planning shall operate Energy transfer
Efficient
Economical
Planning
Coordination
shall operate
SLDC
Provide non-discriminatory
open access
CTU
State Government
Generartors
RPCs
CEA
Licencees
Intra-state transmission system

17. 3. Planning Code for Inter-state Transmission
Introduction
Objective
Scope
Planning Philosophy
Planning Criterion
Planning Data
Implementation of Transmission Plan

18. Introduction Inter-state Intra-State Intra-State STU CTU STU CEA
Transmission schemes for planning and coordination
Transmission schemes for planning and coordination
CEA

19. Scope of planning code (3.3)
Connected to/using/developing ISTS
CTU
ISGS GC
ISTS
SEBs
STU
Licensees
IPP
Objective
specify principles,
specify procedures
specify criteria
promote coordination
information exchange
Generation/Transmission of energy to/from ISTS

20. Planning Philosophy (3.4)
CEA
Long-term plan (10-15 years)
inter/intra state transmission system
continuously updated to reflect load projections and generation scenarios
NEP
Avoid congestion
Annual plan (5 year forward term)
CTU
Identification of major inter state/regional lines including system strengthening schemes
Planning schemes shall also consider:
CEA’s:
Long-term perspective plan
Electric Power Survey of India report
Transmission Planning Criteria and guidelines
RPC Feedback
NLDC/RLDC/SLDC feedback
CERC Regulations
Renewable capacity addition (MNRES)

21. Planning philosophy (contd...)
System strengthening schemes by CTU:
shall be done in consultation with CEA’s Standing Committee for Transmission System Planning:
Planning
On the basis of PPA
No PPA/ no consensus – CTU may approach CERC in accordance with CERC (Grant of Regulatory approval for Capital Investment to CTU for execution of ISTS)
Planning data:
submission by STUs/Users to CTU:

22. Planning philosophy (contd...)
Voltage management by:
capacitors, reactors, SVC and FACTs
similar exercise by STU
STU shall plan to evacuate power from ISTS
ISTS & intra-state transmission systems are complementary & interdependent
If LTA Applications require strengthening of intra-state transmission system – applicant shall coordinate with STU

23. Planning Criterion (3.5)
Planning criterion ISTS’s security philosophyCEA guidelines
a) Without load shedding or rescheduling of generation, ISTS shall
withstand and secure against the following outages:
a 132 KV D/C line, a 220 KV /DC line,
a 400 KV S/C line, 765 KV S/C line
single Inter-Connecting Transformer (ICT )
one pole of HVDC Bi-pole
Outage of 765 kV S/C line
Without load shedding but could be with rescheduling of generation,
ISTS shall withstand and secure against the following outages:
a 400 KV D/C line
a 400 KV S/C line with TCSC
both pole of HVDC Bi-pole line
Outage of 765 KV S/C line with series compensation

24. c) Any one of the events defined above should not cause:
Planning Criterion (3.5)
b) ISTS shall withstand the loss of most severe single system infeed without loss of stability
c) Any one of the events defined above should not cause:
loss of supply
prolonged operation of frequency below and above limits
unacceptable high or low voltage
system instability
unacceptable overloading of ISTS elements 24

25. Planning Data & Implementation
d)All S/S (132 kV & above) shall have at least two transformers
e)CTU will carry out reactive power compensation requirement of ISTS & at ISGS’ switchyard
f)SPS may be planned by NLDC/RLDC in consultation with CEA, CTU, RPC & Regional entities – for enhancing transfer capability or to take care of additional contingencies

26. Planning Data & Implementation
As per CERC (Grant of Connectivity, LTA and MTOA in ISTS and related matters) Regulations 2009
Implementation of Transmission Plan (3.7)
Actual program of implementation of transmission lines, ICTs, reactors/capacitors and other transmission elements as per CERC (Grant of Connectivity, LTA and MTOA in ISTS and related matters) Regulations 2009 26

27. 4. Connection Code OBJECTIVE Minimum technical & design criteria SCOPE
Ensure the safe operation, integrity and reliability of the grid
Non-discriminatory
New/modified connection not suffer or impose unacceptable effects
In advance knowledge about Connectivity
Comply with CEA( Technical Standards for connectivity to the Grid) 2007
Minimum technical & design criteria
SCOPE
CTU
STU
ISTS
Users connected to ISTS or seeking connection to ISTS

28. Procedure for connection (4.4)
User seeking new/modified connection:
Shall submit an application on standard format in accordance with CERC (Grant of Connectivity, LTA and MTOA in ISTS and related matters) Regulations 2009
CTU shall process as per above regulations

29. 4.5 Connection Agreement
Connection agreement would be signed by the applicant in accordance with CERC (Grant of Connectivity, LTA and MTOA in ISTS and related matters) Regulations 2009

30. Reactive Power Compensation 4.6.1
by /STUs and Users in the low voltage systems close to the load points therby avoiding exchange of reactive power to/ from the ISTS
Already connected shall provide additional reactive compensation as per the quantum and time frame decided by the RPC in consultation with RLDC.
Installation and healthiness would be monitored by RPC

31. Data and Communication Facilities (4.6.2)
reliable and efficient speech and communication system to be provided
Users/STU/CTU shall provide systems to telemeter power system parameters
Flow
Voltage
Status of switches
Status of transformer taps
Associated communication system to facilitate data flow up to appropriate data collection point on CTU’s system as specified by CTU in the Connection Agreement 31

32. System Recording Instruments (4.6.3)
Data Acquisition System/Disturbance Recorder/Event Logging facilties/Fault Locator (including time synchronization equipment ) shall be provided and always kept in working condition
Responsibility for safety (4.6.4)
CEA (Technical Standards for connectivity to the Grid), Regulations 2007
CERC (Grant of Connectivity, LTA and MTOA in ISTS and related matters) Regulations 2009
CEA (Safety Requirements for construction, operation and maintenance of electrical and electric lines) Regulations, 2008 32

33. International Connections to ISTS (4.7)
By CTU in consultation with CEA and MOP
Schedule of assets of Regional Grid (4.8)
CTU and other transmission licensees shall submit by 30th Sep a schedule of transmission assets as on 31st March indicating ownership on which RLDC has operational control and responsibility.

34. 5. Operating Code

35. Operating philosophy (5.1)
objective of the integrated operation:
enhance overall operational reliability and economy
Cooperate and adopt Good Utility Practice
NLDC:
overall operation of National/Inter-Regional Grid
develop/maintain detailed internal operating procedures for national grid
RLDC:
overall operation of Regional Grid
develop/maintain detailed internal operating procedures for regional grid

36. Operating philosophy (5.1)
SLDC:
develop/maintain detailed internal operating procedures for State grid
All licensee, generating company, generating station and any other concerned person:
comply with directions of RLDC/SLDC
e) round-the clock manning by qualified and trained personnel of:
control rooms of NLDC, RLDC, SLDC, Power Plant, Sub Stations (132 kV & above)
control centres of all regional constituents 36

37. System Security Aspects (5.2)
Synchronism:
all Users, CTU & STU
operate their power systems/stations in an integrated manner
No deliberate isolation of part of the grid:
except under emergency
safety of human/equipment
when instructed by RLDC
restoration to be supervised by RLDC in coordination with NLDC/SLDC

38. System Security Aspects (5.2)
Important elements list at RLDC:
not removed without RLDC’s consent or prior consent
when specifically instructed
list of important elements to be prepared and shall be put on website of NLDC/RLDC/SLDC
emergency removal intimated to RLDC
tripping, reason, likely time of restoration intimated to RLDC say within 10 minutes
Important elements tripping to be informed to NLDC by RLDC
Prolonged outage sub-optimal operation----monitored by RLDC------report to RPC finalise action plan for restoration 38

39. Restricted Governor Action (5.2(f))
Thermal generating > 200 MW and hydro units > 10 MW on RGMO wef
Gas Units, Combined Cycle, wind, solar & nuclear exempted till CERC reviews
When frequency stabilise at 50.0 Hz FGMO would be intoduced
RGMO
For Frequency < 50.2 Hz no reduction in generation when frequency rises
Any fall in frequency generation should increase by 5% limited to 105% of MCR (thermal), 110% MCR (Hydro)
After increase in generation, the unit mey ramp back to original level at a rate of 1% per minute
At Frequency < 49.7 Hz ramp up could be at higher rate
governors: 3% - 6% droop
any exception: reason & duration to RLDC

40. System Security Aspects 5.2 (s)
Voltage- (kV rms)
Nominal
Maximum
Minimum
765
800
728
400
420
380
220
245
198
132
145
122
110
121 99 66 72 60 33 36 30 40

41. DEMAND ESTIMATION FOR OPERARTIONAL PURPOSES
Inform to
RLDC/
RPC
Wind
Energy
Forecast
ATC/
TTC
By – online estimation of demand for each 15 min block 41

42. Demand Management(5.4) SLDCs shall control demand in the event of:
insufficient generating capacity/inadequate external transfer
breakdown/congestion problems
Demand disconnection
frequency:
below 49.7 Hz: shall initiate action to restrict their net drawal
below 49.5 Hz: requisite load shedding
Each User/STU/SLDC shall formulate contingency procedures and make arrangements. Contingency Procedure to be regularly updated and monitored by SLDC/RLDC
SLDC through respective SEBs/Discoms shall formulate and implement state-of-the-art demand management schemes- roatational load shedding/demand response (which may include lower tariff for interruptible load) etc. SLDC to furnish periodic report to CERC.

43. Demand Management(5.4.2(e)(f)(g)(h))
Interruptible load in four groups:
Scheduled load shedding/power cuts
Unscheduled load shedding
UFR/df/dt loads
SPS loads
RLDC may direct to decrease drawal in contingency---SLDCto send compliance report
SLDC may direct SEB/Discom/bulk consumer to curtail drawal and monitor
RLDC shall devise standard, instantaneous, message formats
Congestion – requisite load shedding or generation backing down . Implementation as per CERC ( Measures to relieve congestion in real time operation), Regulations, 2009 43

44. Periodic Reports (5.5) weekly report by NLDC (put on website):
Performance of national/integrated grid
daily report by RLDC (put on website):
Wind power injection
quarterly report by RLDC :
system constraints, reasons for not meeting the requirements, security standards & quality of service
actions taken by different persons
persons responsible for causing the constraints
weekly report by RLDC (put on website):
Frequency and voltage profiles
Major generation & transmission outages
Transmission constraints
Instances of persistent/significant non-compliance of IEGC
Instances of congestion
Instance of inordinate delay in restoration
Non-compliance of instructions of SLDCs by SEB/Discom
RLDC shall provide information/report to RPC for smooth operation of ISTS 44

45. Operational Liaison (5.6)
Introduction
a) requirements for the exchange of information in relation to Operations/Events on the total grid system which have had or will have an effect on:
National grid
the regional grid
the ISTS in the region
the system of a User/STU
(the above generally relates to notifying of what is expected to happen or has happened and not the reasons why)
b) Operational liaison function is a mandatory built-in hierarchical function of the NLDC/RLDC/SLDC/Users to facilitate quick transfer of information to operational staff

46. Procedure for Operational Liaison
a) Operations and event on the regional grid
before carrying out any operation, RLDC will inform User/SLDC/CTU whose system will be affected
immediately following an event, RLDC will inform the User/SLDC/CTU with details of what happened but not the reasons why
RLDC to NLDC if other region is going to be affected
immediately following an event, NLDC would keep all RLDCs informed
b) Operations and events on a User/STU system
before carrying out any operation that will affect regional grid, constituent shall inform RLDC with details
immediately following an event, the User/SLDC shall inform RLDC with details but not the reasons why
Prolonged Forced outages – monitored at RPC level. RPC shall send a monthly report to CERC

47. Outage Planning (5.7) Introduction
a) procedures for preparation of outage schedules for the elements of the National/Regional in a coordinated and optimal manner and the balance of generation and demand
b) generation output and transmission system should be adequate after taking outages into account to achieve security standards
c) annual outage plan for the financial year shall be prepared by RPC Secretariat and reviewed during the quaterly and monthly basis. ROR, wind & solar power to be extracted to maximum

48. Outage Planning Process
Mar
Jan
Nov
next financial year
proposed outage programmes by all concerned (30th Nov)
Dec
draft outage programme by RPC Secretariat (31st Dec)
final outage programme by (31st Jan)
Feb
Review by RPC Secretariat: adjustments made wherever found to be necessary in coordination with all parties concerned
monthly review
quarterly review

49. Outage Planning (5.7.4) In consultation with NLDC/RLDC
In Emergency – RLDCs may conduct studies before clearance
NLDC/RLDC are authorized to defer
- grid disturbance
- system isolation
- partial black out in a state
- any other critical event
Latest detailed outage plan – updated
Each user, CTU and STU shall obtain one final approval from RLDC
RPC shall submit quarterly, half yearly reports to CERC indicating deviations 49

50. Recovery Procedures (5.8)
Detailed plans/procedures for restoration of partial/total blackout regional grid
develops
RLDC
consultations
reviewed/updated annually
Concerned Constituents
RPC secretariat
develop
Mock trials once every 6 months
DG sets to be tested on weekly basis- quarterly report to be sent to RLDC
Detailed plans/procedures for restoration of partial/total blackout
reviewed/updated annually

51. Recovery Procedures (contd...)
List of the following shall be available with NLDC/RLDC/SLDC:
generating stations with black start facility
inter-state/regional ties
synchronising points
essential loads to be restored on priority
During restoration following blackout, RLDC authorized to operate the grid with reduced security standards for v & f
all communications channels for restoration shall be used for operational communications only till grid normalcy is restored

52. Event Information (5.9) Introduction Responsibility
reporting procedures in respect of events to all Users, STU,CTU RPC secretariat, NLDC/RLDC/ SLDC
Responsibility
RLDC/SLDC shall be responsible for reporting events to the Users/SLDC/ STU/CTU RPC secretariat/ NLDC /RLDC
Users/ STU/CTU /SLDC shall be responsible for collection and reporting all necessary data to NLDC/RLDC and RPC secretariat for monitoring, reporting, and event analysis

53. Reportable events (5.9.5) i Violation of security Standards ii
Grid indiscipline
iii
Non-Compliance of RLDC’s instruction iv
System islanding/ system split v
Regional black out/partial system black out vi
Protection failure
vii
Power system instability
viii
Tripping of any element ix
Sudden load Reduction

54. Reporting Procedure NLDC weekly written report of events Users/STU/
CTU/SLDC
RLDC
written report of events
Form of written reports:
i) Time and date
vi) Duration of interruption
ii) Location
vii) Recording System informations
iii) Plant or equipment directly involved
viii) Sequence of trippings with time
iv) Description and cause of event
ix) Remedial Measures
v) Antecedent Condition

55. 6. Scheduling & Despatch Code
demarcation of responsibilities
procedure for scheduling & despatch
Reactive power and voltage control mechanism
complementary commercial mechanism (Annexure-I) 55

56. OBJECTIVE SCOPE NLDC RLDC SLDC
Procedure for submission of Capability declaration
Procedure for submission of requistion/ drawal schedule by regional entities
Real time despatch/drawal instructions
Rescheduling
Commercial arrangement for UI/Reactive
Scheduling of wind/solar on 3 hourly basis
Appropriate Metering
SCOPE
Discoms
Power
Exchanges
ISGS
NLDC RLDC SLDC
Wind/Solar
generators
Other
concerned
SEBs/STUs

57. Demarcation of responsibilities (6.4) Role of RLDC
Scheduling of CGS (Except where full share is allocated to host state)
Scheduling of GS connected to ISTS
RLDC
Scheduling of GS connected both to ISTS and state grid and home state is less then 50%
Scheduling of UMPP

58. Demarcation of responsibilities (6.4.4) SLDC
Scheduling drawal from ISGS
Permitting Open Access
SLDC
Regulating net drawal
Scheduling and despatching
6.4.8 Demand Estimation in coordination with STU/Discoms
Demand Regulation

59. Demarcation of responsibilities (6.4.6/7)
System of each regional entity shall be operated as notional control area
Regional entity would
regulate its own
generation and load so
that drawals are
close to schedules
Scheduled drawal +
Bilaterals on day
ahead basis
Regional entity would Endeavour
for UI=0 at F<49.7 Hz.
At F< 49.5 Hz ,automatic demand
management scheme/manual
demand disconnection

60. Regional Entities Agreements
Joint/bilateral agreements for
State’s share in ISGS projects
scheduled drawal pattern
tariffs
payment terms
RLDC
RPC
State1
State2
ISGS project1
State3
ISGS project2
State4
ISGS projet3
State5
RLDC/SLDC
Long Term, MTOA
CTU

61. 6.4.9 Role of ISGS/ Generating Station
Declare DC Faithfully
Penalty : Capacity Charges reduced
DC during Peak Hours > Other Hours
6.4.9 Role of ISGS/ Generating Station
Planned Outages
OCC of RPC
When F<49.7 , maximize generation
When F>50.2 , backdown generation
ISGS
Deviation from Schedule UI
Proper Operation and Maintenance
Generate as per despatch schedule advised to them by RLDC

62. CEA (Installation and operation of Meters ) Regulations
Role of CTU
Weekly Readings
Install SEMs
CTU
Constituents
where
SEMs
are
located
CEA (Installation and operation of Meters ) Regulations

63. Demarcation of responsibilities Role of RLDC
Periodically review UI
15 min drawal and injection
Report
RLDC
MS RPC
Gaming by ISGS
105 % in one block of 15 minutes and 101% over a day no gaming

64. Role of RPC
REA, UI, Var Accounting
Outage Planning
RPC

65. Role of NLDC HVDC Settings Trans-National Exhange of Power NLDC
Scheduling of Inter-Regional Power Exchanges
HVDC Settings
Trans-National Exhange of Power
NLDC
Scheduling on Inter Regional Links .
Collective Transaction Scheduling
Energy accounting on IR Links- with RLDC

66. Scheduling & Despatch Procedure (6.5)
List of ISGSs and beneficiaries
all ISGS whose output is shared by more than state shall be listed on RLDC and SLDC websites
the station capacities and allocated/contracted shares of different beneficiaries shall also be listed out
State’ entitlement:
Thermal ISGS:
(foreseen ex-power plant MW capability for the day) X (state’s share in the station’s capacity)
Hydro ISGS:
(MWH generation capacity for the day) X (state’s share in the station’s capacity)

67. Preparing final schedule
ISGS
station-wise MW/MWH capability
final Despatch schedule
Despatch schedule starts
revision
Despatch schedule
RLDC 12 1 2 3 4 5 6 7 8 9 10 11 12 1 2 3 4 5 6 7 8 9 10 11 12 1 AM
noon PM
station-wise W/MWH entitlement
Drawal schedule starts
revision
net Drawal schedule
final Drawal schedule
required Drawal schedule
SLDC

68. Scheduling of Collective Transaction 6.5.5
Power Exchanges
3. Check for Congestion , reworked as per CERC directive
1. List of Interfaces, Control areas
2. Interchanges on Interfaces, Control areas
NLDC
4. Consultation
6. Individual Transactions
7. Schedule individual transaction
SLDC
RLDC
5.Schedule at respective periphery

69. Revision of schedules during the day
any State may revise:
drawal schedule from any/all ISGS within their entitlementsto be effective from 6h time block)
an ISGS may revise:
capability on account of forced outage. (to be effective from 4th time block)
Revision (to be effective from 6h time block)
RLDC can revise:
In the interest of better system operation (to be effective from 4th time block)
Shall formulate procedure for meeting contingency

70. Other Contingencies
In the event of bottleneck in evacuation of power, RLDC may revise the schedules which will be effective from 4th time block and for 1-3 time blocks schedules would deemed to have been replaced by actual.
Similarly for entire period of grid disturbance, schedules will be replaced by actual
No revision – if change in previous schedule/capability is less than 2%.

71. Other Contingencies
For every change in generation schedule there would be corresponding change in drawal schedule
Procedure for recording the communication regarding changes in schedules taking into account to be developed by CTU 71

72. Final schedule & Documentation
RLDC’s final implemented schedule:
shall be the datum for commercial accounting
shall be open for 5 days for verification/correction
RLDC shall properly document the following:
station-wise foreseen ex-power plant capabilities advised by the generating stations
the drawal schedules advised by beneficiaries
all schedules issued by RLDC
all revisions/updating of the schedules

73. Reactive Power & Voltage Control (6.6)
VAR Charges under Low Voltage
VAR Charges under High voltage
EHV grid
EHV grid Q Q
Voltage: < 97%
Voltage: > 103% Q Q
Beneficiary1
Beneficiary2
Beneficiary1
Beneficiary2
VAR charges
VAR charges
Pool Account
Pool Account

74. VAR charges settlement
No VAR charges for its own lines emanating directly from ISGS
VAR charges at the nominal paise/KVArh rate as may be specified by CERC and will be between beneficiaries and POOL (Present rate is 10.0 p/kvarh with escalation of 0.5 p/kvarh every year)
RLDC may direct Regional entity to curtail VAR drawal/injection for safety and security of grid or safety of equipment
Beneficiaries to minimise injection/drawal of VAR if voltage goes beyond + 5%.
ICT taps may changed as per regional entity request to RLDC
Tap changing (400/220 kV)and switching in/out of line reactors (400kV) shall be carried out as per RLDC instruction.

75. Annexure-1 (6.1 d) Complementary Commercial Mechanisms

76. ISGS Generation Cost beneficiary1 UI UI Settlement System UI UI
Capacity charge + Energy charge
beneficiary1 UI UI
Settlement
System UI UI
beneficiary2
Full reimbursement for generation as per the generation schedule
Capacity charge + Energy charge

77. Weekly bills & penalty (12, 13, 14)
UI Settlement
System
Constituents
UI bills
UI payment
RLDC
Pool
Account
RPC
VAR bills
VAR payment
monthly payment status
CERC
payment defaults
payment within 10 days from date of billing
simple 0.04% per day to constituent for delayed payment beyond 12 days.

78. Regional Energy Accounting
Sun
Mon
15-minute block SEM readings for a week
Tue
Wed
Thu
ISTS Connections
Fri
Sat
Weekly raw SEM data 
Sun
Mon
Tue
Wed
Thu
Fri
Sat
Sun
RLDC
Weekly UI and VAR Account 
Constituents
REA
Mon
Tue
Monthly (6th):
RLDC to tabulate UI account and REA in RPC’s CC meeting on a quarterrly basis for audit by the later.

79. Complementary Commercial Mechanism
Money left in VAR account shall be utilized for training of SLDC operators and other similar purposes

80. Thank you!