OPERATING PROCEDURES
FOR
EASTERN REGION
(as mandated by the
IEGC clause 5.1(f))
Revision-0: July 2016
Eastern Regional Load Despatch Centre
14,Golf Club Road, Tollygunge
Kolkata – 700033
ERLDC: POSOCO
Table of Contents
Chapter 1
........................................................................................................................................ 5 1. General .......................................................................................................................................... 5 1.0. Introduction ........................................................................................................................... 5 1.1. Scope ..................................................................................................................................... 5 1.2. Objective................................................................................................................................ 5 1.3. Maintenance of Operating Procedures .................................................................................. 5 1.4. Structure of the Operating Procedure Document .................................................................. 6 1.5. List of Annexure(s) and Reference Documents .................................................................... 6 Chapter 2
........................................................................................................................................ 7 2. Frequency Management ................................................................................................................ 7 2.0. Frequency Standard ............................................................................................................... 7 2.1. High Frequency Conditions ................................................................................................... 7 2.2. Low Frequency Conditions ................................................................................................... 8 2.3. Broad Guidelines for Issue of Over drawl messages ............................................................. 9 Chapter 3
...................................................................................................................................... 12 3. Voltage Management .................................................................................................................. 12 3.0. Introduction ......................................................................................................................... 12 3.1. AVRs of Generators ............................................................................................................ 12 3.2. VAR Exchange by constituents for Voltage and Reactive Control..................................... 12 3.3. VAR generation / absorption by generating units ............................................................... 12 3.4. Transformer Taps ................................................................................................................ 13 3.5. Control of Voltage at grid substations/generating stations .................................................. 13 3.6. Switching off the line reactors in case of low voltage ......................................................... 14 Chapter 4
...................................................................................................................................... 15 4. Outage Planning .......................................................................................................................... 15 4.0. Introduction ......................................................................................................................... 15 4.1. Objective.............................................................................................................................. 15 4.2. Scope ................................................................................................................................... 15 4.3. Outage Planning Procedure: ................................................................................................ 15 4.4. Outage planning not covered in Annual Outage plan.......................................................... 16 4.5. Procedure for Availing the Outage in Real Time ................................................................ 17 Chapter 5
...................................................................................................................................... 19 5. Switching Coordination .............................................................................................................. 19 5.1. Introduction ......................................................................................................................... 19 5.2. Switching of System Elements for first time ....................................................................... 19 5.3. Switching of Important Elements ........................................................................................ 19 5.4. Other Precautions to be taken during Switching ................................................................. 20 5.5. Charging of partly constructed EHV O/H line from one end as an anti-theft measure ....... 21 5.6. Procedure for certifying successful trial operation of new transmission element ............... 22 Chapter 6
...................................................................................................................................... 25 6. Periodic Reports and Event Information..................................................................................... 25 6.0. Introduction ......................................................................................................................... 25 6.1. Objective.............................................................................................................................. 25 2|Page
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6.2. 6.3. 6.4. 6.5. Periodic Reports .................................................................................................................. 25 Event Information ................................................................................................................ 26 Reporting system ................................................................................................................. 26 Grid Incidence/Disturbances and Categorisation ............................................................... 27 Chapter 7
...................................................................................................................................... 28 7. Network Security and Congestion Management ........................................................................ 28 7.0. Introduction ......................................................................................................................... 28 7.1. Network Security ................................................................................................................. 28 7.2. Periodic auditing of protection system ................................................................................ 37 Chapter 8
...................................................................................................................................... 39 8. Scheduling and Despatch Procedure ........................................................................................... 39 8.0. Introduction ......................................................................................................................... 39 8.1. Scope ................................................................................................................................... 39 8.2. Objective.............................................................................................................................. 39 8.3. Description of the procedure ............................................................................................... 39 8.4. Procedure for revising ISGS schedule downwards on account of surrendering of share by
beneficiaries ................................................................................................................................... 40 Chapter 9
...................................................................................................................................... 52 9. SCADA System Operation ......................................................................................................... 52 9.1. Introduction ......................................................................................................................... 52 9.2. Energy Management System ............................................................................................... 52 9.3. Communication System....................................................................................................... 52 9.4. SCADA Features ................................................................................................................. 52 9.5. Operational Requirements ................................................................................................... 52 Chapter 10
...................................................................................................................................... 54 10. Metering and Settlement System............................................................................................. 54 10.0 Introduction ............................................................................................................................ 54 10.1 Metering and Data Collection .......................................................................................... 54 10.2 Automated Meter Reading (AMR) .................................................................................. 54 10.3 Data Processing ................................................................................................................ 54 10.3.1 Energy Accounting .......................................................................................................... 55 10.3.2 Pool Account Operation ................................................................................................... 56 3|Page
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Annexures
Annexure: I Generation capacities in Eastern Region...................................................................... 57
Annexure: II List of Generating Units and their Capacities…………………………………………58
Annexure :III Captive Power Stations in Eastern Region and Their Capacities ............................... 61 Annexure: IV Deviation rate at different frequencies ......................................................................... 62 Annexure: V Format message for violation of IEGC ........................................................................ 63 Annexure: VI List of 765/400kV & 400/220kV ICTs and their tap Positions ...................................... 64 Annexure: VII Reactive Compensation Details ................................................................................... 65 Annexure: VIII Format for message to be issued by ERLDC for Real Time Outage clearance .......... 67 Annexure: IX New transmission element charging and issue of certificate of successful trial run
operation
...................................................................................................................................... 68 Annexure :X Format for Weekly Reports .......................................................................................... 79 Annexure :XI Format for Quarterly Reports ....................................................................................... 81 Annexure :XII Format for written report for event reporting ............................................................... 84 Annexure: XII (a) Format for Reporting System Disturbances ................................................... 85 Annexure :XIII Categorisation of Grid Incidences/Disturbances .......................................................... 88 Annexure :XIV List of Important Elements.......................................................................................... 89 Annexure :XV Automatic UFR load shedding Schemes and Feeder Disconnection to control
overloading
...................................................................................................................................... 96 Annexure :XVI Power Demand Override ........................................................................................... 104 Annexure : XVI Special Protection schemes at Talcher and Kolar ..................................................... 105 Annexure :XVIII Islanding schemes in ER ......................................................................................... 108 Annexure :XIX Scheduling Formats ( Broad guidelines for the Formats) .......................................... 111 Annexure: XX Meter Locations ........................................................................................................ 114 Annexure :XXI Grid Maps.................................................................................................................. 124 Annexure :XXIII :- Format for Applying and Withdrawing congestion ............................................. 134 4|Page
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Chapter 1
1.
General
1.0.
Introduction
In compliance to the IEGC (Indian Elecricity Grid Code) clause no 5.1(f) this internal Operating
Procedure for Eastern Region is developed in consultation with the regional constituents of Eastern
Region. Eastern Region Grid system comprises of the states of Bihar, Jharkhand, Orissa, West
Bengal and Sikkim and has an operating area of 4,25,423 sq km, which is about 13% of the total area
of the country. Damodar Valley Coprporation (DVC) established under sub-section (1) of Section 3 of
the Damodar Valley Corporation Act, 1948 in eastern region is an integrated utility similar to
STU/SEB encompassing part of the states of West Bengal and Jharkhand and has its own generation,
transmission and distribution facilities in its identified command area. Eastern Region is strategically
located and has interconnections with all the other regions as well as with neighbouring countries like
Bangladesh, Bhutan and Nepal.
The IEGC brings together the different terms, encompassing all the utilities connected to / or
using the Inter-State Transmission System (ISTS) and provides documentation in regard to
relationship between various users of the ISTS. It lays down the rules and guidelines for planning,
development, operation and maintenance of the grid in an efficient, reliable and economical
manner.
The internal operating procedure as prepared by ERLDC is to clearly specify the roles of each player
in the grid i.e., Central Sector Generating and Transmission Utilities, State Utilities, Independent
Power Producers, Traders, System Operators and other agencies operating in the power market to
facilitate grid operation in efficient, secure, reliable and economic manner.
1.1.
Scope
This document describes the role of all agencies connected in the region in order to operate the grid
in an integrated manner promoting efficiency, reliability and economy in conformation to the desired
security standards and to meet the common interests of all the agencies.
1.2.
Objective
Objective of this document is to describe the procedures to be adopted for integrated system
operation and roles of each agency and their responsibilities in the grid in compliance to the various
provisions of IEGC. This document aims at operation, maintenance and development of regional
power system in the most efficient, economic, secure and reliable manner. This document also aims
to facilitate beneficial trading opportunities between utilities within as well as outside the region to
harness bottled up power
1.3.
Maintenance of Operating Procedures
The Operating Procedure shall be maintained by ERLDC and reviewed periodically. However, in the
event of any specific operational issues/philosophy requiring urgent revision of the procedure, the
same may be expeditiously carried out in consultation with the Regional constituents. Further,
whenever amendments are made in the IEGC, DSM, Open Access, Congestion management and
related regulations, the operating procedure would be also be amended accordingly.
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1.4.
Structure of the Operating Procedure Document
The Operating procedure of the Eastern Region system contains the following chapters .
Chapter 1 General
Chapter 2: Frequency Management
Chapter 3 Voltage Management
Chapter 4 Outage Planning
Chapter 5 Switching Coordination
Chapter 6 Periodic Reporting and Event information
Chapter 7 Network Security and Congestion management
Chapter 8 Scheduling and Despatch
Chapter 9 SCADA system operation
Chapter 10 Metering & Settlement System
1.5.
List of Annexure(s) and Reference Documents
For the purpose of understanding the operational aspects and issues, there would be a necessity to
refer to various data, lists and parameters, external and internal cuments/lists, Grid Maps etc. A list
of Annexure(s) had been shown at the beginning of this document.
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Chapter 2
2.
Frequency Management
2.0.
Frequency Standard
IEGC vide its clause 5.2(m) has mandated that all Regional entities shall make all possible efforts to
ensure that the grid frequency always remains within the 49.9-50.05 Hz band, Frequency is the most
important indicator of the quality of supply and is the global parameter in the grid i.e. it is same
throughout an inter-connected power system. Since Frequency essentially being a manifestation of
the extent of load-generation balance of the National Grid as a whole, the system operator at ERLDC
needs only to minimize the Area Control Error (ACE) of Eastern Region, provided the same deviates
appreciably, in order to contribute towards system frequency regulation.
Till AGC is implemented in the country, real time values of ACE of individual regional entities as well
as Eastern Region as a whole would be monitored. A negative deviation of ACE indicates overdrawal or under-injection by the control area / regional entity. Conversely, deviation on the positive
side indicates under-drawal or over-injection by the entity.
2.1.
High Frequency Conditions
In case the frequency is high (above 50.05Hz) and is in increasing trend then the following
actions may be initiated:
2.1.1 Control area(s) within E. Region, with high positive deviation of ACE would be first
advised (through their respective SLDC) to maintain their net interchanges as per
schedule. In case any regional entity is under-drawing, ERLDC may advice concerned
SLDC for considering surrendering of its share from ISGS, based on merit order.
2.1.2 ERLDC shall check whether the high frequency condition is due to the heavy underdrawal by any entity within the region or by neighbouring regions. In the latter case, the
matter has to be brought to the notice of NLDC for necessary remedial action Control
area(s) within E. Region. ERLDC shall advise the regional entities within ER to lift load
shedding if any.
2.1.3 However, before taking up with other regions / NLDC, ERLDC would check the possibility
of any backing down of the reservoir based hydro stations within state system.
2.1.4 ERLDC before advising any generation reduction at the hydro stations, in consultation
with concerned SLDC, would check back whether such reduction would cause any
adverse change in voltage levels or network loading in the ISTS. Similarly, the concerned
SLDC would also assess the impact on its intrastate network. In case any problem is envisaged due to such generation reduction, the
same shall be avoided.
2.1.5 Explore the possibility of running of Purulia Pump storage hydro units in pump mode, in
consultation with SLDC, West Bengal.
2.1.6 Advise/remind the states to back down costly generation as per merit order by taking
adequate support from SCADA. The applicable deviation rate as per CERC (w.e.f 17-02-14)
is shown at Annexure IV.
2.1.7 If any ISGS (other than must run) is generating more than their schedule, advise the ISGS
to reduce the over injection.
2.1.8 If the frequency is still high then as per the ”Central Electricity Regulatory Commission
(Ancillary Services Operations) Regulations, 2015”, the NLDC shall trigger the
RRAS(Reserve Regulation Ancillary Services) DOWN service to bring down the frequency
within the permissible upper limit.
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2.1.9 The Hydro stations of Bhutan power system exporting power to India (except Dagachhu
HPS) are not covered commercially under ABT mechanism. Backing down advice on
account of high frequency conditions may be issued to stations at Tala, Chukha and
Kiruchu of Bhutan system only after all possible remedial measures are exhausted.
However, in case the stations are noticed generating extra with respect to schedule
issued , ERLDC shall attempt revising the generation schedule with due revision of
constituents drawal schedule.
2.1.10 Backing down of the spilling hydro units or the run-off-the-river units for short duration may
also be considered if all other options are exhausted.
2.1.11 If the frequency is still high, and action from underdrawing beneficiaries is not forthcoming,
ERLDC shall suo-motto reduce the generation schedule of ISGS with corresponding
downward revision of schedule of the concerned beneficiary.
2.2.
Low Frequency Conditions
If the frequency is less than 49.9 Hz. and has a decreasing trend, the following actions may be
taken:
2.2.1 Control area(s) within E. Region, with high negative deviation of ACE would be first
advised (through their respective SLDC) to maintain their net interchanges as per
schedule.
2.2.2 ERLDC shall check whether the low frequency condition is due to the heavy over-drawal
by regional entities or by the neighbouring regions. In the event of overdrawal by
neighbouring regions, matter may be brought to the notice of NLDC through written
messages with a copy/ies to the RLDC of the over drawing region(s).
2.2.3 If any unit of Purulia Pump storage is operating in pump mode and if the concerned
beneficiary is over drawing, ERLDC shall advise the concerned SLDC for discontinuing
the pump operation.
2.2.4 ERLDC may advise all regional entities / control areas, through their respective SLDCs to
maximize their internal generation viz. hydro, thermal, IPP etc. in case margins are
available.
2.2.5 Deviation Settlement Mechanism and related matters Regulations, 2014. already lays
down appropriate financial and legal penalties for under-generation / over-drawal at low
frequency. Nevertheless, if any ISGS is under-generating, it may be reminded to generate
as per schedule. If such generation increase is not possible due to any technical
constraints, the concerned ISGS
may be advised to reduce its Declared Capability. ERLDC would then correspondingly
reduce the drawal schedules of all concerned beneficiaries (including outside regions) and
advise them to maintain their net exchanges as per their respective revised schedules.
2.2.6 The Actual receipt from the Hydro stations from Bhutan may be closely monitored under
low frequency conditions. In case such receipt is less than the schedule, because of some
technical reasons like low inflow etc., ERLDC may suo motto revise the generation
schedule downwards with corresponding downward revision of drawal schedules of the
respective constituents who have share on such stations. Such downward revision shall
be duly informed to the concerned beneficiaries with an advise to curtail their drawal from
the grid.
2.2.7 If the frequency is less than 49.9Hz. and has a falling trend, remind the SLDC(s) of
overdrawing regional entity /entities telephonically to maintain frequency by picking up
internal generation/ curtailing overdrawal. The estimation of over-drawal has to be done
corresponding to nominal frequency (50.0 Hz) after applying requisite frequency bias
correction on the exchange at the prevailing off-nominal frequency.
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2.2.8 If the frequency is less than 49.9 Hz and it may appear that practically no control area is
as such overdrawing, a general message may be issued to all regional entities requesting
to estimate their respective actual net exchanges at 50.0 Hz (after applying necessary
frequency correction factor on the existing interchange) and improve internal generation/
shed loads wherever the estimated actual drawal corresponding to 50.0 Hz exceeds the
net scheduled drawal.
2.2.9 ERLDC may further examine the latest status of thermal units under outage (forced) and
find out when the units are expected to be on bar and take up for expediting the same.
2.2.10 As a long term measure, It may be examined that whether a planned maintenance of any
unit can be postponed without much affecting the AMP of other units.
2.2.11 Notwithstanding the above as per clauses 6.4.12 of IEGC, ERLDC may direct the
SLDCs/ISGS/ other regional entities to increase/decrease their drawal/generation in case
of contingencies e.g. overloading of lines/transformers, abnormal voltages, threat to
system security. Such directions shall immediately be acted upon. In case the situation
does not call for very urgent action, and ERLDC has some time for analysis, it will be
checked whether the situation has arisen due to deviations from schedules. These shall
be got terminated first, through appropriate measure like opening of feeders , if
considered necessary by SLDC/ERLDC, before an action, which would affect the
scheduled supplies to the long term, medium term customers or short term customers is
initiated in accordance with Central Electricity Regulatory Commission (Grant of
Connectivity, Long-term Access and Medium-term Open Access in InterState
Transmission and Related matters) Regulations, 2009 and Central Electricity Regulatory
Commission (Open Access in Inter-State Transmission) Regulations, 2008.
2.2.12 If the frequency is low then as per the ”Central Electricity Regulatory Commission
(Ancillary Services Operations) Regulations, 2015”, the NLDC shall trigger the
RRAS(Reserve Regulation Ancillary Services) UP service to bring the frequency at or
above the permissible lower limit.
2.3.
Broad Guidelines for Issue of Over drawl messages
Violation Type and Category
Frequency Violation
Voltage Violation
Loading Violation
Duration for issuance of Message
>50.1 Hz or <49.7 Hz
Emergency
Message will be issued if violation
continues for at least 5 minutes
50.05-50.1 Hz or 49.9 Hz
-49.7 Hz
Alert
Message will be issued if violation
continues for at least 15 minutes
49.9 Hz -50.05 Hz
Normal
> 425 kV or <380 kV
Emergency
415 kV - 425 kV or 390
kV - 380 kV
Alert
>390 kV to <415 kV
Normal
> Thermal Loading under
n-1 contingency
Emergency
Message will be issued if violation
continues for at least 5 minutes
= Thermal Loading under
n-1 contingency
Alert
Message will be issued if violation
continues for at least 15 minutes
< Thermal Limit under n-1
contingency
Normal
Message will be issued if violation
continues for at least 15 minutes
Message will be issued if violation
continues for at least 15 minutes
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Zero Crossing
Violation
Deviation Violation
1 Failure (issued 14th time
Block)
Emergency
Issued in 11th time block if
the direction not changed
for 10 time blocks
Alert
Zero Crossing done within
10 time Blocks
Normal
> 20% or 250 MW
(whichever lower)
Emergency
Message will be issued if violation
continues for at least 5 minutes
12%-20% or 150 MW to
250 MW (whichever
lower)
Alert
Message will be issued if violation
continues for at least 15 minutes
<12% or 150 MW
(whichever lower)
Normal
Note:
1. General Approach is to issue Alert Message before reaching Critical level
2. Generally every Alert is considered for maximum of 15 Minutes
3. Generally any Emergency considered for maximum of 5 minutes
4. Only after Emergency message, if correction does not effected in say 5 minutes, Non-Compliance Message
will be issued Separately.
Normal State: All system variables are within the normal range and no equipment is being overloaded.
Alert State: All system variables are within acceptable range, all constraints are satisfied and a further
contingency would cause an overloading any equipment.
Emergency State: After the contingency, voltages at many buses are low and/or equipment loadings are
exceeds short term emergency ratings.
Format for issuance of violation message to the constituents within the region as per IEGC
clause 5.4.2 is shown in Annexure V.
3.
Feeder disconnection in case of over drawl
As per provisions 5.4.2 (a) & 5.4.2 (b) of the Grid Code SLDC/ SEB/distribution licensee and bulk
consumer shall initiate action to restrict the drawal of its control area ,from the grid, within the net
drawal schedule and the SLDC/ SEB/distribution licensee and bulk consumer shall ensure that
requisite load shedding is carried out in its control area so that there is no overdrawl. In order to
maintain the frequency within the stipulated band and maintaining the network security, the
interruptible loads shall be arranged in four groups for scheduled load shedding, unscheduled load
shedding, loads to be shed through UFR / df/dt relays and loads to be shed under SPS identified at
RPC level. Further there should not be any overlapping of loads belonging to different groups. In
case of certain contingencies and/or threat to system security, the ERLDC may direct any SLDC/
SEB/distribution licensee or bulk consumer connected to the ISTS to decrease drawal of its control
area by a certain quantum. In case repeated warning messages from ERLDC to curb over drawal
does not yield any results, ERLDC will instruct the defaulting constituents to disconnect identified
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radial feeders within their respective systems for reduction of over drawl. Concerned constituents
should send compliance report to ERLDC in this regard after taking necessary action. List of feeder
to be disconnected in case of over drawl is shown in Annexure-XV
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3.
Chapter 3
Voltage Management
3.0.
Introduction
In compliance to the IEGC (Indian Electricity Grid Code) clause no 5.2(s) all regional constituents
shall make all possible efforts to ensure that the grid voltage always remains within the following
operating range
Nominal
(KV –Rms)
765
400
220
132
Maximum
(KV –Rms)
800
420
245
145
Minimum
(KV –Rms)
728
380
198
122
Eastern Region Grid has a very good spatial distribution of generation rendering a better voltage
profile across 400 kV and 220kV network. However, in some pockets of system where radial loads
are fed, occasional low voltage is experienced. Normally the 400kV system usually operates within
the prescribed voltage limit as specified in the IEGC. However, in the event of low demand in Bihar or
low import by NR and/or WR, substations like Jamshedpur etc. experience high voltage. On the other
hand, due to high concentration of load in South Bengal, 400kV voltages at Jeerat and Subhasgram
become low, particularly during summer peak. 400kV station at Jeypore, Sasaram, Jeerat etc.
occasionally experience both low and high voltages due to the low fault MVA as well as large
variation of active / reactive demand these stations.
As the HVDC station Gajuwaka is also connected to Jeypore having low fault MVA, any power flow
change associated with switching of filter banks operation render at times wide fluctuations in voltage
at 400kV level.
3.1.
AVRs of Generators
As per the provisions of clause 5,2(k) of IEGC, all generating units shall keep their Automatic Voltage
Regulators (AVRs) in operation and power system stabilizers (PSS) in AVRs be appropriately tuned.
3.2.
VAR Exchange by constituents for Voltage and Reactive Control
In line with clause 4.6.1(a) of IEGC each agency shall provide adequate compensation of its reactive
requirements including appropriate reactive reserves, to support safe and secure power transfer on
interconnecting transmission circuits. The agencies shall take action in regard to VAR exchange with
the grid looking at the topology and voltage profile of the exchange point. In general, the regional
entities shall endeavour to minimize the VAR drawl at interchange point when the voltage at that point
is below the nominal value and shall not inject VARs when the voltage above the nominal value. In
fact, the regional entities are expected to provide local VAR compensation so that they do not draw
any VARs from the grid during low voltage conditions and do not inject any VARs to the grid during
high voltage conditions.
3.3.
VAR generation / absorption by generating units
In order to improve the overall voltage profile, the generators shall run in a manner so as to have
counter balancing action corresponding to low/high backbone grid voltage and to bring it towards the
nominal value. In order to achieve the same, all generators shall generate reactive power during low
voltage conditions and absorb reactive power during high voltage conditions as per the capability limit
of the respecting generating units. The online tap changers (OLTC) on the generator transformer
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wherever possible should also be used to achieve this. Off load tap changes should be used to take
care of the seasonal variations in the voltage profile.
3.4.
Transformer Taps
In line with IEGC clause 6.6.4, the transformer tap positions on different 400kV class ICTs shall
be changed as per requirements in order to improve the grid voltage. ERLDC shall coordinate
and advise the settings of different tap position and any change in their positions shall be carried
out after consultation with ERLDC. A list of tap positions for 765/400KV and 400/220kV ICTs / as
on 30.06.16 is enclosed at Annexure VI. ERLDC shall maintain this list and incorporate due
changes and reasons for change of 400/220kV ICT tap positions. Frequent on line tap changing
may be avoided to the extent possible. Any measure to maintain the voltage profile within the
operating range by way of change of ICT taps may be resorted to through detailed study and
observing the real time voltage profile of the concerned station/s. As a part of such study, ERLDC
shall duly examine from the weekly special energy meter data the pattern of VARh drawal by
regional entities at various ISTS interconnection points at HIGH/LOW voltage. Effort shall be
made to identify such ISTS points where regular VARh charge payment to regional pool takes
place. Necessary measure shall be initiated to set optimum ICT taps so as to minimise such
payment to pool.
Based on SCADA data, voltage data on both high as well as low sides of 400/220kV and
765/400kV transformers would be examined by ERLDC on a half-yearly basis, through 2dimensional scatter plots, with one axis representing the primary side voltage and the other axis
the secondary side voltage . If majority of the data are found to exist in the first or third quadrant
of the plot, then scope does not exist for further improvement of voltage by tap changing.
However, if more than 30% of the data occupy the 2nd or the 4th quadrant, then action for
appropriate changing of ICT tap is initiated, which is further cross-checked by off-line simulation
study.
3.5.
Control of Voltage at grid substations/generating stations
Following corrective measures in order of priority shall be taken by ERLDC operator for ISTS
system and regional entities and by SLDC for state entities in the event of voltage going beyond
the operating limits as stipulated in IEGC.
1.5.1
High Voltage:
In the event of high voltage (e.g. 400 kV voltage going beyond 415 kV and having a rising
trend) following specific steps would be taken by the respective grid substation/generating
station at their own, with intimation to ERLDC, unless specifically mentioned by
ERLDC/SLDCs. Before taking any voltage control action the reason for high voltage as
observed /reported be carefully studied The network adjoining to the substation/s
experiencing high voltage be also carefully studied and areas/substations /generating
stations be identified where voltage control measures need to be taken in the following
order of priority
a) The bus reactor be switched in
b) The switchable line/tertiary reactor are taken in ( a list of Bus reactors /line reactors
and tertiary reactors available at ER grid is enclosed at Annexure VII
c) The Generating units on bar at the stations in proximity to high voltage areas, absorb
reactive power within the limits of their capability curves.
d) Optimization of the filter banks at HVDC terminal (provided high voltage is being
experienced in the vicinity of the terminal)
e) Check the possibility of changing the transformer Tap if one side of ICT is witnessing
High voltage while other side is having low voltage.
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f) Checking possibility of rerouting /change of power flow on HVDC terminals so that
loading on parallel EHV network can be altered that may result in reduction in voltage.
g) ERLDC/SLDCs shall consider opening one circuit of lightly loaded multi circuit lines
around the area /substation where high voltage is reported, ensuring security of the
balance network. In case it becomes essential to switch out one of the circuits of interregional lines to mitigate high voltage at one or more inter-regional sub-stations, due
consent would be obtained from the concerned neighbouring RLDC (s) and NLDC.
1.5.2 Low Voltage Condition
In the event of low voltage(e.g. 400 kV voltage going below 390 kV and have a declining
trend), following specific steps would be taken by the respective grid
substation/generating station at their own, with intimation to ERLDC, unless specifically
mentioned otherwise by ERLDC/SLDCs. However, before taking any voltage control
action, the reason for low voltage as observed /reported is to be carefully studied. The
network adjoining the substation/s experiencing low voltage to be also carefully studied
and areas/substations /generating stations to be identified where voltage control
measures need to be taken in the following order of priority
a)
b)
c)
d)
e)
f)
g)
h)
3.6.
Close the lines which were opened to control high voltage after obtaining due
permission from ERLDC/SLDCs.
The bus reactor be switched out
The switchable line/tertiary reactor be taken out
All generating units on bar shall generate reactive power upto the limits of their
respective capability curves.
Optimization of the filter banks at HVDC terminal
Check the possibility of changing the transformer Tap if one side of ICT is
witnessing Low voltage while other side is having High voltage
Operate hydro generator for VAR generation i.e. at lagging p.f.
Check possibility of altering HVDC power flow settings on HVDC terminals so that
loading on parallel EHV network goes down resulting in rise in voltage.
Switching off the line reactors in case of low voltage
In the event of persistent low voltage conditions, some of the line reactors are to be selected on the
basis of line length, grid conditions, network topology etc., which can be switched off in order to
improve the system voltage profile. The details of all shunt reactors in ER Grid are listed at
Annexure VII of this document. The switching off of such line reactors and reviving them back would
be carried out as per the instructions issued by ERLDC.
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Chapter 4
4.
Outage Planning
4.0.
Introduction
In reference to the clause 5.7.1 of IEGC, this chapter sets out the procedure for preparation of outage
schedule for generating units and transmission elements of the region in a coordinated and optimal
manner keeping in view the regional system operating conditions and maintaining load generation
balance in the system. Adequate security margins shall be ensured while preparation of the
generation and transmission outage programme. ERPC secretariat shall be responsible for
preparation of the annual outage plan in advance for the financial year and be reviewed on monthly
basis.
4.1.
Objective
4.1.1
To formulate a coordinated outage programme of transmission lines and generating units for
the regional grid considering all the available regional resources and taking into account
transmission constraints as well as other requirements.
4.1.2
To minimise surplus or deficit, if any, in the requirement of power and energy and help to
operate system within the grid standards.
4.1.3
To optimise the transmission outages of the elements of the Eastern Regional grid that should
not affect adversely the regional grid operation but take into account the generation outage
schedules, outage of SEB/STU systems thereby maintaining security standards.
4.2.
Scope
The scope of this chapter is applicable to all users viz. SEBs/STUs, ISGSs, IPPs, CTU, ISTS
Licensees as well as RLDC, SLDCs, (vide clause 5.7.3 of IEGC). For the purpose of a coordinated
maintenance programme, outage programme for the generating stations at Bhutan viz. Tala HEP,
Chukha HEP Dagachhu HEP and Kiruchu HEP and its associated transmission system shall also be
covered within the scope of outage planning procedure of Eastern Regional Grid system.
4.3.
Outage Planning Procedure:
4.3.1
For the purpose of Load Generation Balance (LGB)/ Outage planning process, OCC
(Operation Coordination Sub Committee) of ERPC shall, in general, be the forum for
reviewing and deciding the outage planning.
4.3.2
It shall be the responsibility of the ERPC secretariat to analyse the outage programmes
proposed by various agencies and, prepare a draft annual outage schedule for finalization of
the annual outage plan for the following financial year by 30th November of each year.
4.3.3
All SLDCs/STUs, CTU, ISGS, IPPs, shall provide RPC Secretariat their proposed outage
programmes in writing for the next financial year by 31st October of each year. These shall
contain identification of each generating unit/ transmission line/ICT, the preferred date for
each outage and its duration and where there is flexibility, the earliest start date and latest
finishing date.
4.3.4
Each load serving control area shall be responsible to match its demand with the anticipated
availability from its own plant(s) and availability from ISGS / other purchase / sale contracts.
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4.3.5
The SLDC/STUs along with the proposed outage programme, therefore, shall also furnish
details of the anticipated load generation balance report(LGBR) to ERPC secretariat in order
to facilitate preparation of the annual outage plan
ERPC Secretariat after receiving the outage programme will study the following :i)
Total power and energy availability( for peak and off-peak condition)
ii)
Monthwise availability and requirement
iii)
In case of both surplus and deficit, proper staggering of generation outage to
reduce/ eliminate the deficit.
iv)
In case of only deficit efforts to be taken to even out high and low deficit by
staggering of generation outage.
v)
The anticipated programme for bilateral transaction under STOA or otherwise by
state beneficiaries
4.3.6
ERPC Secretariat shall then come out with a draft load generation balance report (LGBR) and
draft outage programme for the next financial year by 31st December of each year for the
Regional grid taking into account the available resources in an optimal manner and to
maintain security standards. This will be done after carrying out necessary system studies and,
if necessary, the outage programmes shall be rescheduled. Adequate balance between
generation and load requirement shall be ensured while finalising outage programmes.
4.3.7
The final outage plan alongwith the Load Generation Balance report(LGBR) shall be prepared
in consultation with NLDC and RLDC and intimated to NLDC, Users, STUs, CTU, other
generating stations connected to ISTS and the RLDC for implementation latest by 31st
January of each year as mutually decided in ERPC forum.
4.3.8
Shutdown planning of any element affecting power exchange with Bangladesh or Bhutan will
be done in consultation with NLDC.
4.3.9
The above annual outage plan shall be reviewed by ERPC Secretariat on quarterly and
monthly basis in coordination with all parties concerned, and adjustments made wherever
found to be necessary.
4.4.
Outage planning not covered in Annual Outage plan
4.4.1
Some of the outages not foreseen while finalising annual outage plan will be considered in
monthly OCC meeting of ERPC.
4.4.2
Indenting Agency: The agency which gives the requisition for outage of any power system
element shall be called Indenting Agency. Any of the following may request for outage of any
power system elements:
4.4.2.1 Transmission Licensees / State Transmission Utilities
4.4.2.2 Generating Companies
4.4.3
Indenting Agency shall submit the proposed shutdown for the next calendar month latest by
3rd day of the current month to the RPC Secretariat as per Format IA / Format IB. In the said
proposal apart from the main power system element(s) to be taken out of service and its
purpose, the agency should also mention the duration of non-availability of each sub-station
equipment such as bus section, CB, isolator or any other switchgear as well as non-availability
of any protection feature or PLCC, in as much detail as possible.
4.4.4
In case of shutdown of inter-regional lines and intra-regional lines affecting the transfer
capability of any inter regional corridor, the Indenting agency shall submit the shutdown
proposal in both the concerned RPCs. To facilitate this, broad list of such lines is indicated at
Annexure XIV which will be reviewed and updated by NLDC from time to time. The indenting
agency may do an internal screening of its outage plan centrally to avoid multiple outages in
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the same corridor simultaneously. Bilateral discussion between the agencies involved may
also be done to minimize outage duration before submitting the outage plan to RPCs.
4.4.5
ERPC Secretariat shall compile all the received proposals and put up the same on its website
by 5th day of the month as per Format IIA / Format IIB.
4.4.6
System Study sub-committee of ERPC shall study the impact of these outages and based on
its recommendations, ERPC shall discuss proposed outages in the OCC meeting and prepare
a list of approved transmission outages with the precautions to be taken. ERPC would attempt
to schedule all their OCC meetings between 10th to 15th day of the month so that sufficient
time is available both to the Study Committee before the OCC meetings as well as for
ERLDC/NLDC (mainly to take care of further changes in the network topology and/or in load
generation) after the OCC meeting.
4.4.7
While approving the shutdowns it shall be ensured that multiple outages in the same corridor
are not be approved simultaneously. It also needs to be ensured that all other concerned
entities also complete their maintenance works requiring the same shutdown during the same
period so that multiple shutdowns of any particular element for maintenance work by multiple
agencies are avoided. Multiple outages of transmission element for the same work during the
year may also be avoided.
4.4.8
ERPC shall send the list of approved transmission outages to SLDCs/ERLDC/NLDC within 3
days of the OCC meeting and preferably latest by 18th of the month as per Format IIIA /
Format IIIB. The same shall also be displayed on ERPC websites.
4.4.9
Any shutdown proposal which requires approval of two RPCs shall be considered approved
only if it is approved in both the RPCs.
4.4.10 After the receipt of Format IIIA / Format IIIB from each RPC, NLDC in consultation with
RLDCs may prepare a tentative readjusted timings/dates of transmission element outages for
next month considering the principles set out in this procedure
4.4.11 In case of emergency in the system, viz., loss of generation, break down of transmission line
affecting the system, grid disturbances, system isolation, RLDC may conduct studies again
before clearance of the planned outage.
4.4.12 Vide clause 5.7.4 (g) of IEGC ERLDC is authorised to defer any planned outage in case of
any of the following taking into account the statutory requirements:
i) Major grid disturbances (Total black out in Region)
ii) System isolation / separation
iii) Black out in a control area
iv) Any other event in the system that may have an adverse impact on the system
security by the proposed outage.
4.5.
Procedure for Availing the Outage in Real Time
4.5.1
The agencies involved shall ensure availing of outages as per the approved schedule time.
4.5.2
Request for outages which are approved by OCC must be sent by the owner of the
transmission asset at least 3 days in advance to ERLDC by 10:00 hours, together with the
details mentioned under 4.4.3
4.5.3
In case the owner is not availing the OCC approved outage, the same shall be intimated to the
ERLDC at least 3 days in advance with a copy to MS/ERPC for approval from ERPC side.
After due communication from ERPC, ERLDC will process accordingly.
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4.5.4
In case the owner is not availing the OCC approved outage, the same shall be intimated to the
respective RLDC at least 3 days in advance.
4.5.5
In case the outage of inter-regional links or any 765 kV links or any links outage which need
ATC revision, RLDCs shall forward the request for shutdown along with their consent and
observation as per Format V to NLDC/other concerned RLDCs with clear observations
regarding possible constraints /contingency plan and consent including study results by 10:00
hours
of
D-2
day.
Other
concerned
RLDCs
would
forward
their
observations/consent/reservations by 16:00 hours of D-2.
4.5.6
A list of all the outages approved for the next day shall be forwarded to NLDC for all India
compilation.
4.5.7
On the day of outage, the outage availing agency shall seek the code for availing outage from
ERLDC/NLDC (wherever applicable). The agencies involved shall endeavour to avail the
outage with in 15mintues of availing the code but not later than 30 minutes. In case, due to
any contingency, the outage could not be availed within 30 minutes, a fresh code needs to be
obtained by all concerned agencies stating the reason there of. Record of scheduled and
actual time of outage and restoration shall be maintained at ERLDC/NLDC.
4.5.8
ERLDC shall prepare a monthly statement of scheduled and actual time of outage and
restoration and forward the same to ERPC latest by 05th day of the next month with a copy to
NLDC.
4.5.9
SLDCs shall prepare a monthly statement of scheduled and actual time of outage and
restoration and forward the same to ERPC latest by 05th day of the next month with a copy to
ERLDC..
4.5.10 As any deviation in the outage from the schedule can affect other planned outages as well as
affect reliability and electricity markets, indenting agency must strictly adhere to the shutdown
timings
4.5.11 ERLDC if required shall conduct further system studies based on the system condition and
approve the shutdown at least two day in advance.
4.5.12 While issuing clearance of the shutdown ERLDC shall clearly mention the following( vide
format at Annexure VIII)
i)
Message no.
ii)
Name of the element /elements which shall remain under outage.
iii)
Name of the agency /agencies availing the outage.
iv)
Date and duration of the outage
v)
Nature of the outage
vi)
Reason for availing the shutdown
vii)
Specific network /system conditions to be maintained including impact of the outage
viii)
Sequence of switching instruction if any
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5.
Chapter 5
Switching Coordination
5.1.
Introduction
Coordination of switching operations in the grid is important for ensuring safety of personnel and
equipment as well as for ensuring adequacy and security of the grid. Before any operation of
important elements of the Eastern Regional Grid is carried out on a User/STU system, the Users,
SLDC, STU, CTU, licensee shall inform ERLDC, in case the Eastern Regional grid may, or will
experience an operational effect.
5.2.
Switching of System Elements for first time
In line with Regulation 6 (1) of the Central Electricity Authority (Grid Standards) regulations 2010, no
entity shall introduce an element in the ISTS of Eastern Grid without the concurrence of ERLDC in the
form of an operation code. In case a new power system element in Eastern Regional grid is likely to
be connected with the Inter-State Transmission System or is to be energized for the first time, from
the ISTS, the applicant User/STU/CTU/licensee shall send a separate request in advance along (at
least one week) with the confirmation of the following:
 Acceptance of ERLDC with regards to registration as regional entity
 Signed Connection Agreement if applicable
 Availability of telemetry of station/Element at the ERLDC/SLDC
 Availability of voice communication with the station at ERLDC/SLDC
 Interface meter installed and tested by downloading data and forwarding it to ERLDC
 Single Line Diagram
 Healthiness of Protection System/Protection Setting
 Statutory clearance has already been obtained
5.3.
Switching of Important Elements
In line with regulation 5.2 (a, b, c), of the IEGC no part of the Eastern Regional grid shall be
deliberately isolated from the rest of the National/Regional grid except under an emergency
conditions in which such isolation would prevent a total grid collapse and would enable early
restoration of power supply or safety of human life; when serious damage to a costly equipment is
imminent and such isolation would prevent it; when such isolation is specifically instructed by ERLDC.
Important elements of the regional grid, which have a bearing on the network security, is
compiled and issued by ERLDC as a separate document [IEGC 5.2 (c)]. The regional entities, users,
STU, CTU, licensee shall obtain ‘operation code’ from ERLDC before carrying out any switching
operation on any of the important elements of the Eastern Regional grid. Shut down of any 400 kV or
765kV bus at substation needs approval of ERLDC.
In respect of double main and transfer switching scheme at 400 kV substations, ERLDC shall
be informed whenever the 400 kV transfer bus at any substation is utilized for switching any line/ICT.
In a 400 kV substation/power station switchyard having breaker and a half switching scheme, outage
within the substation (say main or tie circuit breaker) not affecting power flow on any line/ICT can be
availed by the constituents under intimation to ERLDC, however switching code must be taken from
ERLDC control room for every such switching operation.. Further, while availing such shutdowns or
carrying out switching operations it must be ensured that at least two Dias are complete even after
such outage from the view point of network reliability. Any outage not fulfilling the above conditions
needs the approval of ERLDC.
Whenever any protection system such as Bus Bar protection, LBB protection, Auto reclose
etc. at generating station or grid substation is required to be taken out of service for any maintenance
work, an operational code would be taken from SLDC/ERLDC.
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For switching of any 765 kV element, or element associated with inter-regional lines or
element associated with power transfer to Bangladesh/ Bhutan/ Nepal, code of both NLDC as well
as ERLDC is required.
5.4.
Other Precautions to be taken during Switching
In addition to the above, it is necessary that special attention be paid to maintaining the reliability of
the system. The following areas need careful implementation by the concerned constituents / stations
i.
In case of a two-bus system at any substation it must be ensured that the segregation of
feeders on the different buses is uniform. This would help in minimizing the number of
elements lost in case of a bus fault. This is assuming the availability of bus-bar protection at
such substation(s).
ii. In 400 kV substations having a breaker and a half scheme, it must be ensured that the two
buses at such substation remain connected at least by two parallel paths so that any line / bus
fault does not result in inadvertent multiple outages. In case any element, say a line or an ICT
or a bus reactor, is expected to remain out for a period say beyond two hours at such
substation, the main & tie breakers of such elements should be closed after opening the line
side isolator. This should be done after taking all suitable precautions to avert inadvertent
tripping. This of course assumes that no maintenance is planned on such breakers / isolators.
iii. When the circuit breaker controlling the line is under lockout it is not advisable to interrupt the
charging current through an isolator. The following practice is to be adopted in such cases:a. De-energise the bus connecting the line with lockout CB and then open the isolator
b. If due to some reason it is not possible to open the isolator in above mentioned way, it
is to be opened in such a way that no charging current is interrupted through the
isolator and the charging current is diverted to other parallel path. Such switching
sequence could be possible in case of breaker and half scheme or Double breaker
Scheme, which is as follows:
i. Open the line from remote end first with direct trip (DT) disabled. With this now
line remains charged from the end where CB has problem.
ii. In case of breaker and half scheme open the isolator so that charging current is
diverted to the parallel path and after that open the CB of parallel path.
iii. In case of double breaker scheme open the isolator of the lockout breaker
diverting the charging current to other CB and then open the CB.
iv. In case of double main and transfer scheme open the isolator of lockout
breaker so that divert the charging current through transfer bus coupler and
then open the line through TBC circuit breaker.
It is also recommended that while vacating a bus in such cases, the operators need to
check the switching arrangement for individual feeders so as to avoid unintended loss
of any feeder.
iv. The substation operators must ensure the above condition even when any lightly loaded
line is opened to control overvoltage. Such opening of lines is generally superimposed
over other line outages on account of faults created by adverse weather conditions
resulting in reduced security of the system.
v. Single pole auto-reclose facility on 400 kV / 220 kV lines should always be in service.
ERLDC’s approval would be required for taking this facility out of service. Likewise, in
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case any transfer breaker at any 400 kV substations having two main and transfer bus
scheme is engaged, the same would be informed to ERLDC.
vi. All precautions should be taken to avoid switching on to fault particularly in case of
Interconnecting Transformers. In order to avoid fault current through costly equipment
generally the line shall be charged from the far end, wherever possible.
vii. A transmission line shall preferably be charged from the grid substation. Dead line
charging by a generator shall normally be avoided except during system restoration, black
start, or in case where both ends of the transmission line are terminating at a generating
station.
viii. During test charging of transmission line for the first time, all safety precautions shall be
taken and the transmission utility owning/operating the line shall satisfy the substation
utility at either ends with regards to statutory/safety clearances. During test charging if the
line does not hold even after two attempts, thorough checking of protection settings and
line patrolling shall be carried out.
ix. Operation code issued by ERLDC for switching shall become invalid if the switching is not
completed within half an hour of issue of code. In case the switching operation is not
completed within half an hour of the issue of operation code from ERLDC, and if there is a
probability of further delay same code could be revalidated by ERLDC within that half an
hour. The utility obtaining at one end shall intimate the other end utility.
Charging of partly constructed EHV O/H line from one end as an anti-theft
measure
5.5.
A number of EHV AC and HVDC O/H lines that have been planned either as ISTS strengthening
schemes or as ATS of identified generation projects are under various stages of construction /
commissioning in different regions. Incidents of theft of conductor / tower members of these
partly constructed new lines are observed to be on the rise. In view of this, CTU / ISTS licensees
are compelled to keep the partly constructed line energised from one end, as an anti-theft
measure. Requests for using existing 132kV / 220kV lines for the purpose of anti-theft charging
are frequently received at ERLDC.
In this regard, the following guidelines may be followed by all ISTS licensees / CTU / STU:a) Efforts to be made to charge the line as far as possible from the nearest distribution
line (11kV / 33kV), after obtaining due approval from the concerned SLDC / DISCOM
b) For this purpose, the CTU/ISTS Licensee to approach the concerned SLDC / STU at
least 15 days in advance of the tentative date of anti-theft charging, with a detailed
plan indicating length proposed to be charged, duration of such charging, height,
spacing etc. of the individual phases / conductors, size of the conductor that would
remain charged, , connection arrangement with existing distribution line etc.
accompanied by a clear diagram.
c) STU / SLDC after examining the proposal may accord approval, if feasible, with
necessary modifications of protection scheme of their distribution system.
d) In the event it is not possible to identify suitable distribution line for the anti-theft
charging or obtain approval of the concerned SLDC, the owner of the line under
construction shall approach, ERPC apprising the difficulties in charging from
distribution line, with a detailed proposal for anti-theft charging from the nearest 132kV
line or 220kV line. In general, charging from a line of voltage higher than 132kV should
be avoided to the extent possible.
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e) On receipt of such request, ERPC to constitute a committee comprising
representatives from ERPC, NLDC, ERLDC, owner of the new line, STUs / SLDCs
likely to be affected and CTU for a joint study on the effects of such interconnection on
the integrated grid.
f) The said committee within 15 days shall recommend the modifications required /
actions to be taken for ensuring compliance to CEA Technical Standards on Grid
Connectivity, CEA Regulation (Measures relating to Safety and Electricity
Supply), IEGC, and Grid Standards so far as protection, speech and data
communication and safety of personnel are concerned, besides reliability of the grid as
a whole. However, if the above conditions are not satisfied, the committee may even
advise the transmission line owner not to attempt anti-theft charging of the partly
constructed line.
g) On completion of the recommended modifications / precautionary actions, the line may
be charged with due consent of the concerned RLDC.
5.6.
Procedure for certifying successful trial operation of new transmission element
Regulation 5(2) of CERC (Terms and Conditions of Tariff), 2014 provides for certification of
successful trial operation of new transmission assets by RLDC. The same is quoted below:
“Trial operation in relation to a transmission system or an element thereof shall mean successful
charging of the transmission system or an element thereof for 24 hours at continuous flow of power,
and communication signal from sending end to receiving end and with requisite metering system,
telemetry and protection system in service enclosing certificate to that effect from concerned Regional
Load Dispatch Centre”
Procedure
In accordance with the above provisions and as a part of NLDC/RLDC operating procedure, the
procedure for interconnection of a new transmission element belonging to any transmission licensee
has been formulated to enable RLDCs / NLDC monitor and certify secure and reliable interconnection
of new elements. The details of the same are as follows:
(i) All the Transmission Licensees intending to commission any transmission element, which is a
part of inter‐state transmission system, shall intimate the concerned RLDC the details as given
below, generally (10) days prior to the anticipated date of first test charging.
a. Annexure A1: Intimation regarding anticipated charging of the line along with the list
of the desired documents being submitted as per Format I.
b. Annexure A2 : List of elements to be charged and Element Rating details as per
Format IA
c. Annexure A3 : Single line diagram of the concerned sub stations, along with status of
completion of each dia/bus/breakers clearly indicating which elements are proposed to be
charged.
d. Annexure A4 : List of SCADA points to be made available (as per standard
requirement, RLDC would need all MW and MVAr data, voltage and frequency of all the
buses, all the breaker and isolator positions, OLTC tap positions, Main‐1/Main‐2 protection
operated signals)
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e. Annexure A5 : Location of Energy meters as per relevant CEA regulations
f.
Annexure A6 : Connection Agreement, wherever applicable along with all annexures.
(ii) In addition to these documents, charging instructions, details of approval of the transmission
scheme from the Standing Committee / CTU, availability of line reactors as per approved
scheme, approval for changes in the approved scheme, technical parameters of the transmission
element required for network modeling shall be made available by CTU/STU, as the case may
be, to RLDCs/NLDC.
(iii) Within 3 days of submission of above information by the Transmission Licensee, concerned
RLDC shall acknowledge the receipt of the same, as per Format II, and seek clarifications, if
any. The transmission licensee shall submit the desired information/documents to the
concerned RLDC within next three days.
(iv) The request for charging of new transmission element and towards start of the trial
operation as per Format III shall be submitted by the Transmission Licensee to the
concerned RLDC, generally three (3) days prior to the date of first time charging. There could
be a separate schedule for test charging and the final schedule for trial operation, which
may be mentioned in the Format‐I itself. The Transmission Licensee shall also submit the
following documents in this regard:
a. Annexure B1: Request for charging of the new transmission element along with the
summary of the undertakings being submitted as per Format III
b. Annexure B2: Undertaking in respect of Protective systems as per Format III A
c. Annexure B3: Undertaking in respect of Telemetry and communication as per Format
III B
d. Annexure B4: Undertaking in respect of Energy metering as per Format III C
e. Annexure B5: Undertaking in respect of Statutory clearances as per Format III D
(v) On satisfying itself with the submitted information as stated above under Para 3, the RLDC
would issue a provisional approval for charging to the Transmission Licensee as per Format IV
within two days of receipt of above documents. On the designated day, the transmission
licensee shall charge the transmission line and do trial operation as per the timeline mentioned
in Format III, after obtaining the real time code from RLDC. All attempts would be
made by the real time operating personnel at the concerned RLDC to facilitate charging and
commissioning of the new element at the earliest, subject to availability of real time data
and favourable system conditions.
(vi) Post successful trial operation, following documents shall be submitted by the Transmission
Licensee:
a. Annexure C1 : Request for issuance of successful trial operation certificate as per
Format V
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b. Annexure C2: Values of the concerned line flows and related voltages as per local
SCADA just before and after charging of the element.
c. Annexure C3 : Special Energy meter (SEM) Reading corresponding to the trial run
d. Annexure C4 : Output of Disturbance Recorders / Event Loggers
(vii)
Within three (3) working days of submission of the information mentioned above,
RLDC concerned shall issue the certificate for successful completion of trial run of the
transmission element as per Format VI.
(viii)
In case of an inter‐regional element, both the respective RLDCs would be involved and
a copy of the communications may be forwarded to NLDC also in such cases. NLDC would
issue certificate for successful completion of trial run of the transmission element as per
Format VI.
All the formats mentioned above have been enclosed as Annexure IX
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6.
Chapter 6
Periodic Reports and Event Information
6.0.
Introduction
Timely and accurate reporting and exchange of information plays an important role in grid operation.
This assumes more importance during an occurrence/ a disturbance or in crisis. Timely and accurate
information flow under such conditions would help operators in making an informed decision and
reduces uncertainty. This chapter describes the event information and reporting procedure in writing
to all Regional entities, ERPC Secretariat/ERLDC/SLDC in accordance with the provisions of clause
5.9 of IEGC. This section in accordance with clause 5.5 describes the different periodic reports to be
prepared by RLDC to be sent to all entities of the region and ERPC Secretariat
6.1.
Objective
The objective of this chapter is to define the incidents to be reported, the reporting route to be
followed and information to be supplied to ensure a consistent approach to the reporting of
incidents/events. The Objective of the periodic reports are to highlight performance of the Regional
Grid, bring out the system constraints, reasons for not meeting the requirements, if any, of security
standards and actions taken.
6.2.
Periodic Reports
5.2.1
Weekly Report
As per clause 5.5.1 (C) of IEGC, ERLDC shall be responsible for issuance of weekly report
that shall cover the performance of the Regional Grid for the previous week. ERLDC shall
ensure that such weekly report be available at its website. The report shall be sent to all
Regional entities and ERPC Secretariat and shall contain the following i. Frequency Profile
ii. Voltage profile for selected substations
iii. Major Generation and Transmission Outage
iv. Transmission Constraints
v. Instances of persistent/significance non compliance of IEGC
vi.
Instances of congestion in transmission system.
vii.
Instances of inordinate delays in restoration of transmission elements and
generating units
The format for weekly report is shown at Annexure X
5.2.2
Quarterly Reports
A Quarterly report ( vide clause 5.5.2 of IEGC)shall be issued by ERLDC to all Regional
entities detailing the power supply positions during the last quarter, quality of supply, the
system constraints being faced and the agencies responsible causing constraints.
The format for quarterly report is shown at Annexure XI
5.2.3
Exceptional Reports
In case of any contingency such as industrial unrest, natural calamity etc., there could be
additional reporting requirements not covered in the above schedule. ERLDC shall inform all
regional entities of any such exceptional requirements and the entities would extend all
necessary cooperation in this regard.
5.2.4
Under frequency Relay(UFR) Operation Report
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In accordance with clause 5.2(n) of IEGC , all distribution licensees / STUs shall provide automatic
under-frequency and df/dt relays for load shedding in their respective systems, to arrest frequency
decline that could result in a collapse/disintegration of the grid, as per the plan separately finalized by
the concerned RPC and shall ensure its effective application to prevent cascade tripping of
generating units in case of any contingency. They shall inform (through their respective SLDCs) any
UFR operation that has taken place in their system and the areas affected with approximate quantum
of load relief obtained
6.3.
Event Information
5.3.1 Vide clause 5.9.5 any of the following events require reporting by ERLDC/ Regional
entity
i)
Violation of security standards
ii)
Grid indiscipline
iii)
Non compliance of RLDC’s instructions
iv)
System islanding / system split
v)
Regional blackout / partial system blackout
vi)
Protection failure on any element of ISTS and or any item on the agreed list of the
intra-state systems
vii)
Power system instability
viii)
Tripping of any element of the regional grid
ix)
Sudden load rejection in regional entity’s control area
5.3.2
Any tripping of an element of 220 kV and above or others as listed under the list of important
elements of regional grid, whether manual or automatic, shall be intimated by the control
centre of the regional entity to ERLDC in a reasonable time say within 10 minutes of the
incident. Along with the tripping intimation, the reasons for tripping (to the extent known) and
the likely time of restoration shall also be intimated. Such information can be on telephone, fax
or e-mail.
5.3.3
Any operation planned to be carried out by a regional entity which may have an impact on the
regional grid or on any of the important element, shall be reported by the concerned SLDC to
ERLDC in advance.
5.3.4
Any operation planned to be carried out on the instructions of ERLDC which may have an
impact on the system of a regional entity shall be reported by ERLDC to the concerned SLDC
in advance.
5.3.5
The intimation and the exact time of revival of any element under the category of important
events shall be furnished to ERLDC as early as possible.
6.4.
Reporting system
The details of event reports and periodic reports to be prepared and issued by regional entities /
ERLDC are as follows:
5.4.1
5.4.2
In the event of tripping of any important elements, the preliminary event report with possible
details shall be sent by the SLDC of the concerned regional entity to ERLDC within a period of
three hours of the occurrence of the event and the detailed event report in the form detailed
under the section 5.9.6(C) of IEGC (contents vide Annexure XII) shall be sent within the
next day.
Such report shall follow the telephonic / flash reporting by the concerned SLDC say within a
reasonable time say within 10 minutes of the occurrence of the event as stated under Para
5.2(d)
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6.5.
Grid Incidence/Disturbances and Categorisation
As per the severity of any events/incidences CEA has formulated the guidelines for categorisation of
Grid incidences and disturbances. Any event to be reported may therefore need to be categorised as
detailed below
6.5.1. Grid Incident
A Grid incident is tripping of one or more power system elements of the Grid like a generator,
Transmission line, Transformer, Shunt Reactor, Series capacitor, Static VAR Compensator (SVC) etc,
with no loss of grid supply or integrity of the grid at 220kV and above.
Categorisation of Grid incidents based in increasing order of severity
Category: 1
Tripping of one or more power system elements of the grid like a generator ,
transmission line, transformer, shunt reactor, series capacitor, Static VAR
Compensator(SVC) etc which requires rescheduling of generation or load
without total loss of supply at a sub-station or loss of integrity of the grid at
220kV (132kV in case of NER)
Category:2
Tripping of one or more power system elements of the grid like a generator ,
transmission line, transformer, shunt reactor, series capacitor, Static VAR
Compensator(SVC) etc which requires rescheduling of generation or load
without total loss of supply at a sub-station or loss of integrity of the grid at
400kV and above (220kV in case of NER)
6.5.2. Grid Disturbance
Grid disturbance is defined as tripping of one or more power system elements resulting in total failure
of supply at a sub-station or loss of integrity of the grid, at the level of 220kV and above (132kV and
above in case of NER)
Categorisation of Grid Disturbance in increasing order of severity is described as under.
Category 1: When less than 10% of the antecedent generation or load in a Regional Grid is
lost
Category 2: When 10% to less than 20% of the antecedent generation or load in a Regional
Grid is lost.
Category 3: When 20% to less than 30% of the antecedent generation or load in a Regional
Grid is lost
Category 4: When 30% to less than 40% of the antecedent generation or load in a Regional
Grid is lost
Category 5: When 40% or more of the antecedent generation or load in a Regional Grid is
lost.
ERLDC shall maintain a log (Vide Annexure XIII) of such incidences/disturbances and whenever
such incidences/disturbances occur shall report in writing (vide Annexure XII) as enumerated at para
5.4
Note:
i) Any forced outage of ISGS generator would cause rescheduling of generation and
corresponding revision of drawal. Therefore, this should be treated as Grid incidence.
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7.
Chapter 7
Network Security and Congestion Management
7.0.
Introduction
This chapter describes the actions required to be undertaken by system operators to maintain the
security of the network at all times against any plausible contingencies /outages within the ER
network as well as from any contingencies arising out due to incidences occurring in the rest of the
National grid that may have an adverse effect on ER system.
7.1.
Network Security
7.1.1. Background
The Indian power grid is one synchronous grid viz “NEWS” Grid comprising of Northern, Eastern,
North Eastern, Western region and Southern Region grid. With formation of the NEWS Grid, there
has been sea change in the operational philosophy in system operation that has already yielded
various benefits like peak/off peak demand management through diversity of time, surplus/deficit
management due to seasonal resource variations, demand forecast errors, weather variations
besides increased economic transactions, improvement in overall system security due to increased
stability margin and a higher stiffness to the tune of 6500-7000 MW/Hz. Eastern Region is
strategically located with synchronised interconnections with all the other regions of the NEW Grid
besides having synchronous integrated operation with Bhutan Power system. Eastern Grid is also
connected to Southern Region through two no HVDC interconnections having a total capacity of
3500MW capacity. The large number of synchronous interconnections of Eastern Region with other
regions/neighbouring country like Bhutan and radial connection with Nepal and with Bangladesh
through B-t-B HVDC link has also resulted in evolution of contingencies of critical nature under
different despatch/demand scenarios.
In addition, system may operate at times beyond the assumptions of the planner in line with various
transmission security standards and associated criteria mentioned in section 3.5 of IEGC due to
following reasons:
a) Planned maintenance programme of the generators and transmission lines. It is imperative to
ensure that such maintenance programmes are properly coordinated and do not result in reduced
redundancy not envisaged during planning.
b) The events beyond the control of operators such as extreme
weather conditions affecting the
reliability of transmission
system, uneven demand growth or delay in commissioning of
generators/transmission elements.
7.1.2. Measures to ensure Network Security and Reliability
In order to maintain the security of the Regional power system, it is important that the planned
outages of generation and transmission system particularly in the corridors of important flow-gates
are properly coordinated. A list of important Regional Grid elements (vide clause 5.2(c) of IEGC) of
the Eastern regional grid which have a bearing on the network security are shown at Anneure-XIV. It
is therefore necessary to carry out operational studies in order to assess the grid security and
network stability while finalizing the annual outage plan of these important elements. The outage
planning should be reviewed during the quarterly and monthly review of ERPC OCC forum.
Additionally, any opening of the important elements have to be carried out only after prior Intimation
to ERLDC as enumerated in the ‘Outage planning Procedure’. In the event of tripping of any of the
important elements, ERLDC need to be informed at the earliest time indicating the likely time of
restoration. It is necessary that special attention is paid for maintaining the reliability of the system.
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7.1.2.1.
Assessment of Transfer Capability (Total Transfer Capability(TTC) and
Available Transfer Capability(ATC))
While a Transmission system is built, inherent design margins are kept in order to take care of
reliability and security issues, future generation growth, ROW issues, cost optimisation etc. The
interregional interconnections as have been planned and over the years had also taken care of
such margins. However, since power flow takes place as per the laws of physics and with more and
more AC interconnections between Areas/Regions the transfer between two or more regions gets
restricted because of factors like generation despatch conditions, loop flows between regions,
upstream or down stream network limitations, voltage and angular differences between critical buses
etc. Thus the Total transfer capability between areas is equal to or less than the aggregated design
capacity of interconnection/s and therefore need to be assessed through power system studies well in
advance considering the load / generation balance forecast to a fair degree of accuracy.
“Total Transfer Capability (TTC)” means the amount of electric power that can be transferred
reliably over the inter-control area transmission system under a given set of operating conditions
considering the effect of occurrence of the worst credible contingency.
“Transmission Reliability Margin (TRM)” means the amount of margin kept in the total transfer
capability necessary to ensure that the interconnected transmission network is secure under a
reasonable range of uncertainties in
“Available Transfer Capability (ATC)” means the transfer capability of the inter-control area
transmission system available for scheduling commercial transactions (through long term access,
medium term open access and short term open access) in a specific direction, taking into account the
network security. Mathematically ATC is the Total Transfer Capability less Transmission Reliability
Margin.
STOA- Bilateral+Collective
ATC
Medium Term Open Access
Long Term Access
TTC
Reliability margin
It is therefore imperative that the exchanges between regions are contained to a level of ATC
and in no case exceed the TTC between the regions. All the regional entities of Eastern Region
and / or neighbouring region(s) will adhere to their levels of net interchanges as advised by
ERLDC whenever such breach in TTC level among the regions takes place to ensure the grid
security irrespective of frequency and schedule.
Assessment of Total Transfer Capability (TTC), Transmission Reliability Margin (TRM) and Available
Transfer Capability (ATC) for import and export of power in Eastern Region as required for reliable
system operation and for facilitating non-discriminatory open access in transmission shall be carried
out by ERLDC in coordination with National Load Despatch Centre and other RLDCs.
The ‘Detailed Procedure for Relieving Congestion in Real Time Operation’ as approved by the CERC
vide order dated 22.04.2013 may be referred for further details. The assessed TTC, TRM and ATC
shall be posted on ERLDC/NLDC website.
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The detailed procedure for assessment of TTC, monitoring and invoking congestion
conditions in real-time, application of Congestion Charge and Congestion Charge accounting
and settlement shall be as per the regulation / procedure issued / approved by CERC
7.1.2.2.
Generation Rescheduling
ERLDC may revise the interchange schedule as allowed by IEGC regulation 6.4.12, 6.5.5, and 6.5.16.
Further details may be seen in the chapter on scheduling.
7.1.2.3.
Curtailment of Scheduled Transactions
The transactions already scheduled may be curtailed by ERLDC in the event of transmission
constraints; congestion in the grid, or in the interest of grid security. In line with regulations 6.4.12,
6.5.28, 6.5.30 and 6.5.31 of IEGC the transactions shall generally be curtailed in the following
sequence for deviation from schedule
a. Short term bilateral transactions
b. Short term collective transactions
c. Medium term transactions
d. Long-term transactions
Amongst the customers of a particular category, curtailment shall be carried out on pro rata basis.
ERLDC would curtail a transaction at the periphery of the Regional entities. SLDC (s) shall further
incorporate the inter-se curtailment of intra State entities to implement the curtailment.
7.1.2.4.
Procedure for Relieving Congestion
Congestion Management shall be as per the detailed procedure for relieving congestion in real time
operationas approved by CERC vide its order dated 22.04.2013. It is important to note that the
congestion charge could be applied both upstream and downstream of the congested corridor
irrespective of the frequency. Whenever actual flow on inter/ intra regional link/ corridor exceeds
Available Transfer Capability and security criteria are violated for continuously two time blocks, the
National Load Despatch Centre may issue a warning notice. In case SLDC observes congestion
within the Intra State grid it shall take appropriate action and inform the respective RLDC which in
turn shall inform the NLDC. The notice for congestion shall be communicated to all the Regional
entities telephonically or through fax/voice message/ e-mail and through postings on website and
making the same available on the common screen at NLDC/ RLDCs/ SLDCs. The various formats
may be referred in the detailed procedure for relieving congestion in real time operation under
regulation 4 (2) of the Central Electricity Regulatory Commission (Measures to relieve congestion in
real time operation) Regulations, 2009.
In addition to above, Nodal Agency(NLDC) may issue instruction for Regulation Up / Regulation
Down to any RRAS provider, through concerned RLDC, in line with the Central Electricity Regulatory
Commission (Ancillary Services Operations) Regulations 2015, in case of likelihood or occurrence of
violation of n-1 criteria for any of the transmission corridor or violation of ATC of any flow gate.
7.1.2.5.
Defence Mechanism
Despite utmost caution exercised during operational planning and implementing all the above
steps to improve the network security and reliability, the possibility of a contingent situation
cannot be totally ruled out. It calls for suitable defence mechanism to be available in the system
to take care of such contingencies. Following are the minimum schemes which should be
operational in Eastern Region to ensure safe and secure grid operation.
i) Automatic Under Frequency Load Shedding Scheme.
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In line with clause 5.2(n) of IEGC, all regional entities shall provide Automatic Under Frequency
Load Shedding in their respective system to arrest frequency decline that could result in a
collapse / disintegration of the grid as per the scheme formulated by ERPC forum and shall
ensure its effective application and functionality at all times to prevent cascade tripping of
generating units in case of any contingency. ERLDC shall inform ERPC Secretariat about
instances when the desired load relief is not obtained through these relays in real time operation.
ERPC Secretariat shall carry out periodic inspection of U/F relays and maintain proper records of
the inspection. It is extremely important that there should be no overlapping between the areas
covered by under frequency load shedding and that included in the manual load shedding plan
as part of demand control. The approved Automatic Under Frequency Load Shedding Scheme at
Annexure XV
ii) Special Protection scheme
Such schemes are required to take care of some special contingencies and operate under
specific contingency conditions.
Power Demand Over (PDO) ride at Gazuwaka and Talcher
The Power Demand Override at HVDC stations control systems provide the features when power
flow through HVDC System gets automatically changed to pre-set value when declared
contingencies such as tripping/overloading of elements or tripping of generators take place.
The HVDC back to back station at Gazuwaka having a transfer capacity of 1000 MW( 500 MW
per pole block) is utilised for transfer of power from Eastern Region to Southern region. The
station is connected to Jeypore 400kv substation of CTU in Eastern Region through D/C twin
moose line. Jeypore substation is in turn connected to Indravati (PowerGrid) and Bolangir
(PowerGrid) through S/C 400kV lines. Jeypore has further connectivity to 220kV system of
OPTCL via 2x 315MVA ICTs. However under heavy power transfer to Gazuwaka(SR) from
Jeypore tripping of any of the element as mentioned above might give rise to a contingent
condition leading to cascade tripping of one or more elements within south Orissa network. In
order to circumvent this contingency condition following special protection system of power
demand override has been implemented at Gazuwaka HVDC station
Similarly PDO at Talcher and Kolar is also designed to a preset value under certain
contingencies. These PDOs are described at Annexure XVI
Special protection system at HVDC Talcher( SPS 450 and SPS 1000)
Talcher Super thermal power station having a capacity of 3000MW( 6x500 MW) is located in
Orissa of Eastern Region. The station was commissioned with 2x500MW capacity and
subsequently its second stage was commissioned and station capacity was augmented to
3000MW with commissioning of its further 4x 500MW machines.
The station is the largest capacity station in the region. However, the capacity of the entire stage
II ( 4x500 MW) was allocated to the beneficiaries of southern region. Subsequently, 10% of the
capacity was allocated to the Orissa, in Eastern region. For evacuation of Talcher STPS –II
generation to Southern Region, +/- 500kV HVDC bipole transmission system was commissioned
right upto the load centre of Southern Region at Kolar. The HVDC substation at Talcher has two
pole blocks 1000MW capacity each( subsequently augmented to 1250MW ).
The very basic design of the evacuation system of Talcher stage II to SR poses a major threat to
Eastern Region and subsequently to the New Grid as any sudden forced outage of one or both
the poles would mean that Eastern Grid has to initially absorb a jerk of load throw off to the tune
of 1800-2000MW . The surplus power would get wheeled through Talcher-Rourkella 400kV D/C
765 kV Angul – Jharsuguda S/C and 400 kV Rengali –Baripada-Kolaghat S/C. During monsoon
as such these corridors remain heavily loaded and such contingency of pole block at Talcher
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would lead to a definite cascade tripping leading to isolation /possible collapse of Orissa system
including TSTPP station. In order to avoid such contingency two automatic special protection
schemes were envisaged and have been implemented at Talcher Super Thermal power station.
The 1st scheme as commonly known as SPS 450 was first implemented and subsequently a
further improvised 2nd scheme was devised as known as SPS 1000 scheme. Both the schemes
and their modalities of arming and disarming is described below:
SPS 450: This scheme was originally implemented with a view that Eastern and Western Region
would absorb a jerk of 450 MW therefore rest of the generation as available at Talcher stage II
generation must be shed in order avoid a cascade tripping of the network. However, during
monsoon, from Eastern Regional point of view at times absorbing even 450MW under N-1
contingency criteria of Talcher-Rourkella 400kV D/C Line becomes critical when major
generation at Talcher stage II must be shed in order to avoid further criticality of the Grid. Further
under any critical outage condition in the rest of the New Grid outage of HVDC bipole might pose
a serious threat when it might necessitate arming of SPS -450 scheme with due coordination
with NLDC. The Scheme is described below
SPS 1000: Post formation of the NEW Grid this scheme was subsequently envisaged in order to
minimise shedding of generation at Talcher STPP. The basic philosophy of this scheme is to
absorb 1000MW in place of 450 MW as the Grid size increased. However, as one of the
prerequisites for arming this scheme Eastern Regional operator has to ensure that sufficient
evacuation margin( approx 1000 MW) is available at the AC evacuation system of TSTPP. The
scheme is described below:
Both SPS 450 and SPS 1000 schemes are described at Annexure XVII
Modification in Talcher-Kolar SPS in ER Region due to Synchronisation of SR grid with
NEW grid (Additional 600MW Gen Reduction):
Background
In Southern Region, there is a provision for load shedding in three groups depending on the
power loss on HVDC (Trip Signal 1 for 800 MW load shedding, Trip Signal 2 for 700 MW
additional load shedding, Trip signal 3 for 500 MW additional load shedding considering
extended operation of HVDC in the 2000-2500 MW range). So a total of 2000 MW shedding is
envisaged in Southern Region.
In the NEW grid side of Talcher-Kolar HVDC bipole, there is automatic reduction/tripping of
generation at Talcher Stage-II of NTPC. Two schemes are available at Talcher Stage-II; SPS 450
and SPS 1000 where the number indicates the quantum of power injected into the NEW grid
after tripping of Talcher-Kolar HVDC pole or bipole. In SPS 450, three units are tripped at
Talcher Stage-II while in SPS 1000, a maximum of one unit is tripped and the balance reduction
in generation achieved through fast automatic reduction of generation.
In normal operation, SPS 1000 is armed and in some exceptional cases such as an outage of
elements in the NEW grid, SPS 450 is activated. There are instances when a single pole trips on
line fault and the other pole goes to ground return. In such cases, the healthy pole retries thrice
for going to metallic return and in case it fails, it goes in ground return mode where there is a
restriction of 150 MW.
There have been instances when the Talcher-Kolar SPS fails to operate leading to high
frequency in the NEW grid and low frequency in the Southern Grid. Post 765 kV SholapurRaichur in operation, the impact of any failure of Talcher-Kolar SPS would lead to wheeling of
additional power to Southern Region through the NEW grid creating insecure conditions. In fact,
even injection of 1000 MW into NEW grid and inadequate load shedding in Southern Region can
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lead to insecure conditions as the entire power would be wheeled through 765 kV SholapurRaichur. So, additional safeguards are required.
Triggering the SPS and SPS action
In case of single pole or bipole outage or blocking of Talcher-Kolar HVDC sensed at Talcher
HVDC terminal, a trip signal is extended to nearby generators such as Sterlite, GMR, JITPL
ensuring minimum communication so that the objective of restricting injection to NEW grid is
achieved. The reduction in generation to be achieved through these stations is 600 MW. This
would be in addition to SPS 1000 already in operation at Talcher-II.
SPS 1000 will be functional as it is with additional relief of 600 MW in the event of Talcher- Kolar
pole tripping to ensure grid security.
Presently after commissioning of JITPL additional 600 MW quantum of generation reduction is
shared in following ratio: - Sterlite- 200 MW, GMR-200 MW and JITPL- 200 MW.
Special protection system at SEL (Sterlite Energy Limited)
SEL have a total installed capacity of 2400 MW ( 4 x 600 MW) is located in Odisha. Out of these
four units second unit (Unit-2) is dedicated to Odisha and is connected at separate 400 kV Bus
(400 kV OPTCL bus) which also have 2 x 315 MVA 400/220 KV ICT installed. The 220 kV side of
this SEL bus is connected with 220 kV VAL (Vedanta Aluminium limited) through 220 kV SELVAL D/C.
The remaining three unit at SEL (Unit 1, 3 & 4) is connected to other 400 kV Bus at SEL (400 kV
PGCIL bus) which further have two outgoing lines connected to it, one to Rourkela and one to
Raigarh. In turn these two lines i.e 400 kV SEL-Raigarh S/C and 400 kV SEL-Rourkela S/C is
used to evacuate power from SEL.
SPS at SEL continuously monitor flow of all 400 kV lines and it gets actuated whenever flow of
any line touches 650 MW. In case flow of any line exceeds 650 MW, generation reduction at SEL
took place to bring the line loading under limit.
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CASE 1 (400kV Buses are Decoupled) a) Contigency:-Tripping of 400kV SELROURKELA (PGCIL LiLO-1)
Effect:‐ Over Loading of 400kV SEL‐Rourkela(beyond 650 MW)‐LIL0‐2
CILMS Action Depending up on flow of 400kV SEL‐ Rourkela if Loading is greater than 650 MW but Grid Export Violation Value less than 30% of Priority one Generator MW(say Gen1)
i)
CILMS Action :‐ Tripping of Priority one Generator HPLP (among Unit 1,3 and 4)
if Grid Export Violation Value is greater than 30% of Priority one Generator MW(say Gen1) but less than sum of 30% of Priority one Gen MW and 30% Prioriy two Gen MW(if Prio2 Gen not available in the network then prio3 Gen will concider)
ii)
CILMS Action :‐ Tripping of Priority one Generator HPLP and Prio2 Generator HPLP (if Prio2 Gen not available in the network then prio3 Gen will concider among Unit 1,3 and 4)
iii)
if Grid Export Violation Value is greater than 30% of sum of all available Generators MW in the network but less than Priority one Gen MW (say Gen1)
CILMS Action :‐ Tripping of Priority one Generator (among Unit 1,3 and 4)
if Grid Export Violation Value is greater than Priority one Generator MW(say Gen1) but less than sum Priority one Gen MW and 30% Prioriy two Gen MW(if Prio2 Gen not available in the network then prio3 Gen will concider)
iV)
CILMS Action :‐ Tripping of Priority one Generator and Prio2 Generator HPLP (if Prio2 Gen not available in the network then prio3 Gen will concider among Unit 1,3 and 4)
CASE 1 (400kV Buses are Decoupled) b) Contigency:-Tripping of 400kV SELRAIGARH (PGCIL LiLO-1)
Effect:‐ Over Loading of 400kV SEL‐Raigarh(beyond 650 MW)‐LILO‐2
CILMS Action Depending up on flow of 400kV SEL‐ Raigarh
if Loading is greater than 650 MW but Grid Export Violation Value less than 30% of Priority one Generator MW(say Gen1)
i)
CILMS Action :‐ Tripping of Priority one Generator HPLP (among Unit 1,3 and 4)
if Grid Export Violation Value is greater than 30% of Priority one Generator MW(say Gen1) but less than sum of 30% of Priority one Gen MW and 30% Prioriy two Gen MW(if Prio2 Gen not available in the network then prio3 Gen will concider)
ii)
CILMS Action :‐ Tripping of Priority one Generator HPLP and Prio2 Generator HPLP (if Prio2 Gen not available in the network then prio3 Gen will concider among Unit 1,3 and 4)
iii)
if Grid Export Violation Value is greater than 30% of sum of all available Generators MW in the network but less than Priority one Gen MW (say Gen1)
CILMS Action :‐ Tripping of Priority one Generator (among Unit 1,3 and 4)
if Grid Export Violation Value is greater than Priority one Generator MW(say Gen1) but less than sum Priority one Gen MW and 30% Prioriy two Gen MW(if Prio2 Gen not available in the network then prio3 Gen will concider)
iV)
CILMS Action :‐ Tripping of Priority one Generator and Prio2 Generator HPLP (if Prio2 Gen not available in the network then prio3 Gen will concider among Unit 1,3 and 4)
1
2
* In GS Display Two separate Export setpoint is given for PGCIL GRID
PGCIL Grid Export Setpoint (if Both the PGCIL Grid Lines are Connected)
PGCIL Single Grid Export Setpoint (if only one PGCIL Grid Line connected)
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SPS for power transfer to Bangladesh
Bheramara back-to-back HVDC station with a capacity of 500 MW was commissioned in October
2013 in Bangladesh. Bheramara is connected to Behrampur in West Bengal, India through a 400
kV D/C line. 400 kV Farakka-Jeerat was LILOed at Behrampur to facilitate power transfer to
Bangladesh. Keeping in mind low voltage problems at Jeerat and system security, the following
SPS was devised and put into operation:
S.
No.
Triggering Criteria for
SPS
SPS actions (signal shall be
generated to do following)
Signal to be sent
Bheramara (Yes/No)
1
Voltage at 400kV
Behrampur going below
390kV
To trip 80 MVAR Bus reactor at
400kV Behrampur.
No, Local action at
Behrampur.
2
Voltage at 400kV
Behrampur going below
380kV, the SPS shall
generate a signal.
To ramp down HVDC set-point to
350 MW (with Appropriate Filter
switching to maintain Bheramara
Voltage)
Yes
3
If the frequency goes
below 49.5 Hz.
To ramp down HVDC set-point to
350 MW (with Appropriate Filter
switching to maintain Bheramara
Voltage)
Yes
4
If the 400kV FarakkaBehrampur line flow goes
above 780 MW (Flow
may touch 800 MVA).
To ramp down HVDC set-point to
350 MW (with Appropriate Filter
switching to maintain Bheramara
Voltage)
yes
5
Tripping of 400kV
Sagardighi-Baharampur
D/C as well as FSTPSBaharampur S/C (sensed
by opening of CB
contacts at Baharampur)
To ramp down HVDC set-point to
350 MW (with Appropriate Filter
switching to maintain Bheramara
Voltage)
yes
iii) Islanding Scheme
To avoid total black out of the grid during system disturbances and for early normalisation, the
procedure for islanding of systems and major generating stations with associated loads need to be
developed constituent wise/system wise. The islanding schemes as in operation in Eastern Region is
shown at Annexure XVIII
7.1.2.6.
Switching Diagram
The switching diagrams of all generating stations (100 MW and above), 400kV, important 220kV
and 132kV substations especially those involved in the evacuation of generation shall be made
available to ERLDC system operator at SCADA Desk. The selection of such diagrams is
described at Chapter 8.
The same shall be updated from time to time.
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7.1.2.7.
Operational Areas of Importance
The following areas needs careful implementation by the concerned constituents / stations:i)
In case of a 2 main & transfer bus system at any sub-station, it must be ensured that the
segregation of feeders on the different buses is uniform. It would help in minimizing the
effect on the system in case of a bus fault.
ii)
In 400kV substations having one and half breaker scheme, it must be ensured that each
feeder remains connected to both the buses so that any bus fault does not result in
inadvertent outage of feeders. In case any element, say a line or an ICT or a bus reactor,
is expected to remain out for a prolonged period at such substation, the main and tie
breakers of such elements should be closed after opening the line side isolator. This
should be done after taking all suitable precautions to avert inadvertent tripping.
iii)
The substation operators must ensure the above condition even when any lightly loaded
line is opened to control over voltage. Such opening of lines is generally superimposed
over other line outages on account of faults created by adverse weather conditions
resulting in reduced security of the system.
iv)
Single pole auto reclose facility on 400kV lines should always be in service. Approval of
ERLDC would be required for taking this facility out of service. Likewise, in case any
transfer breaker at any 400kV substations having two main and transfer bus scheme is
engaged, the same would be informed to ERLDC.
v)
In order to damp out the low frequency oscillations in the system, the power system
stabilizers on the generating units would be tuned as per the programme drawn at ERPC
forum. in consultation with the constituents.
vi)
All regional entities would endeavor to operate the connected generation and reactive
power management devices such as Capacitors, Reactors, Synchronous Condensers,
Fixed Series Capacitors (FSCs), Static Var Compensators (SVCs) etc in a manner which
enables stable voltage behavior at various points of the grid under different operating
conditions.
vii)
All regional entities would also maintain in good operating conditions of all control
measures such as defence mechanism, SPS, U/F & U/V load shedding, AVRs, PSS,
FGMO, Operating reserves, emergency back-up power supplies etc., and ensure that the
operational security standards are maintained for reliable and secured operation of the
interconnected
system.
viii)
In line with sections 5.2(f) of the IEGC, the generating units should ensure free governor
operation.
7.1.2.8.
i)
ii)
Recording Instruments, Voice and Communication Facilities
The recording instruments such data acquisition system, disturbance recorder event logger,
fault locator, time synchronization equipment voice recorder and any other such equipment in
each generating station / sub-station / control centre / SLDCs / ERLDC shall be kept in good
working condition in order to record the events and sequence. All such places shall have a
common time reference whose authenticity shall be ensured by periodic verification and
validation procedure to be developed and monitored by ERPC Secretariat.
Each regional entity shall provide adequate and reliable communication facility internally and
with other constituents / RLDC
to ensure exchange of data / information necessary to
maintain reliability and security of the grid.
All the agencies shall provide systems to telemeter power system parameters such as power
flow, voltage and status of switches/transformer taps etc., in line with interface requirements
and other guidelines made available to RLDC / SLDCs atleast before the date of commercial
operation of the generating stations or substation/line being connected to the ISTS.
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iii)
iv)
v)
In line with Central Electricity Authority (Technical Standards for Connectivity to Grid)
Regulations 2007, the requester and user shall provide necessary facilities for voice and data
communication and transfer of online operational data such as voltage, frequency, line flows
and status of breaker and isolator position and other parameters as prescribed by the
appropriate Load Despatch Centre and agree to maintain the communication system in good
condition.
In line with Central Electricity Authority (Technical Standards for Connectivity to Grid)
Regulations 2007, every generating station and substation connected to the grid at 220kV or
above shall be provided with disturbance recording (DR) and event logging facilities. All such
equipment shall be provided with time synchronization facility for common time reference.
For a high degree of service reliability under normal and emergency operation, at least one
main telecommunication channel with an alternate backup channel shall be provided
7.1.2.9.
Monitoring of System States (Grid Health)
As a corollary to the provisions laid down in the IEGC chapter on Operating Code for Regional
Grids, ERLDC has the responsibility of monitoring the state of the regional grid at all times.
The state of the grid has been classified as either NORMAL or ALERT or EMERGENCY,
depending on whether certain security criteria are violated or not, as stated below. The display
system in control room has been accordingly modified to alert the operator, in case the state
of the grid passes to either to ALERT mode or EMERGENCY mode. The Boolean conditions
for various modes are as follows:
NORMAL mode – (50.05 Hz Grid frequency  49.9 Hz) AND (No Flowgate limit, as specified
by operator violated)
ALERT mode – Actual flow through Flowgate-1  Limit specified by operator
OR
Actual flow through Flowgate-2  Limit specified by operator
OR
Grid Frequency  49.9 Hz & > 49.7 Hz
OR
Grid Frequency > 50.2 Hz
EMERGENCY mode – (Resultant output of ALERT mode) AND (Grid Frequency  49.7 Hz)
7.2.
Periodic auditing of protection system
With a view to ensuring security of the integrated grid at all times, the Task Force on “Power System
Analysis Under Contingencies” in its report recommended periodic auditing of the protection system
of every region.
Accordingly, auditing of all sub-stations / power stations of ER grid is to be carried out every year.
For this purpose, one or two teams comprising representatives from ERPC Secretariat, POWERGRID,
ERLDC and an STU (other than the one being audited) would be constituted by PCC and the team
would visit the substations to be audited as per a schedule chalked out by PCC.
All substations / power stations of the region that are of 220kV and above, would be covered within
the scope of the audit.
For the purpose of audit, the team would follow a checklist which has been finalised in ERPC forum.
The same is given in Annexure. The checklist by and large encompasses all the points as mentioned
in the report of the Task Force on “Power System Analysis Under Contingencies”.
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On completion of audit, the teams would submit their observations and recommendations on the
corrective actions to be taken, if any, by the concerned STU/ GENCO or CTU. If there is any scope
for improving the existing protection infrastructure, the audit team may also recommend the same.
Action plan for implementing the recommendations of the protection audit would be prepared in RPC
forum and the same would be regularly monitored/ reviewed in monthly PCC meetings.
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Chapter 8
8.
Scheduling and Despatch Procedure
8.0.
Introduction
The broad principles and guidelines to be followed for scheduling and dispatch of power in the
regional ISTS and the demarcation of responsibilities for this purpose are in accordance with Part 6 of
the IEGC.
8.1.
Scope
This procedure is applicable to ERLDC and other RLDCs, all the thermal and hydro ISGSs on which
beneficiary constituents have shares, the beneficiary constituents of Eastern Region and any regional
entity. For the purpose of implementation of the schedules for import of power from Hydro stations in
Bhutan, this procedure shall also be applicable to the hydro stations of Bhutan
8.2.
Objective
This chapter deals with the procedures to be adopted for scheduling of the inter-State generating
stations (ISGS) and net exchange of regional entities on a daily basis with the modality of the flow of
information among the ISGS/RLDCs/entities of the Region. The procedure for submission of
capability declaration by each ISGS and submission of exchange schedule by each beneficiary is
intended to enable RLDCs to prepare the dispatch schedule for each ISGS and exchange schedule
for each beneficiary. It also provides methodology of issuing real time dispatch/drawal instructions
and rescheduling, if required, to ISGS and beneficiaries.
8.3.
Description of the procedure
The Regional grids shall be operated as power pools (with decentralized scheduling and dispatch), in
which the States shall have operational autonomy, and SLDCs shall have the total responsibility for (i)
scheduling /dispatching their own generation (including generation of their embedded licensees), (ii)
regulating the demand of their customers, (iii) scheduling their drawal from the ISGS (within their
share in the respective plant’s expected capability), (iv) arranging any bilateral interchanges, and (v)
regulating their net drawal from the regional grid. The system of each State shall be treated and
operated as a notional control area. The algebraic summation of scheduled drawal from ISGS , longterm access , medium term and short-term open access arrangements shall provide the drawal
schedule of each State, and this shall be determined in advance on daily basis. The regional entities
shall regulate their generation and / or consumers’ loads so as to maintain their actual drawal from
the regional grid close to the above schedule. The regional entities, through their SLDCs shall always
endeavour to restrict their net drawal from the grid within their respective schedules.
The introduction of the scheduling and despatch mechanism as mandated in IEGC, has further
evolved the framework for developing other power markets such as Short term open access
transactions and collective transactions that can fit in with the scheduling and despatch procedures
as mandated in IEGC. Further CERC has also issued regulation on Short Term and and Collective
transactions and procedure for short term and collective transactions have been duly issued by CTU
and approved by CERC. Therefore procedure as issued by CTU on Short term and Collective may
be referred separately as a part of this procedure. In order to understand the procedure and bring in
more clarity the scheduling and despatch procedure has been prepared in the form of flow chart as
described below:
The entire activities are broadly divided into three parts namely
(i) Day ahead scheduling
(ii) Revision of schedules
(iii) Implementation of Final schedules
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All the relevant formats are enclosed at Annexure XIX
Under fuel shortage conditions, thermal ISGSs may face constraints in adhering to the usual
scheduling procedure. They may propose to deliver a higher MW during peak-load hours by saving
fuel during off-peak hours, in pursuance to Clause 21(4) of the CERC Terms and Conditions of Tariff
2009-14. The broad guidelines to be followed for scheduling ISGSs under such conditions are as
follows:
 Fuel shortage would be declared by the generating stations on a day ahead basis only and
status cannot be changed during the day of operation even if fuel supply status changes,
except in case of unit tripping.
 The concerned plant shall declare its energy capability (MWh), maximum ex-bus
generation (MW) and minimum possible ex-bus generation (MW) that can be maintained.
 Utilities may requisition based on their requirements either as average MW in all time
blocks or different MW in different time blocks upto the entitled maximum MW remaining
within the total energy entitlement for the day. The default would be average MW during all
blocks for those beneficiaries whose time-block wise requisition is not received by RLDC.
 Peak hours shall be of minimum three hours duration as decided on a regional basis
through Operational Coordination sub Committee (OCC) meetings of the RPC. In between
the month changes could also be done by RLDC with advance declaration of two days.
The OCC can also decide peak hours as more than 3 hrs based on regional load curves
either in one continuous spell or two spells for covering morning and evening peak hours.
[e.g. one and half hour continuous or 1 hour and 2 hour continuous in each spell].
 DC for the day in such an event shall be taken to be equal to the maximum peak-hour expower plant MW schedule specified by the concerned Load Despatch Centre for that day.
Procedure for revising ISGS schedule downwards on account of surrendering of
share by beneficiaries
8.4.
As already mentioned in this chapter, the beneficiaries of an ISGS have full autonomy in deciding
their respective requisitions from the ISGS. Thus, in the event of low demand as well as high
availability from own generating stations, a beneficiary may either not requisition its full share or even
prefer to forgo its full share from the ISGS. Such surrendering by multiple beneficiaries of a thermal
ISGS for a particular time period , may cause the despatch schedule of the station to become less
than the minimum level of generation technically achievable by the thermal units. Under such
circumstances ERLDC will moderate the requisitions of the under-requisitioning beneficiaries in a
manner so that unrealistic backing down or shutting down of thermal unit can be avoided. The
general philosophy to be adopted is as follows:
8.4.1. Before issuance of revision 0 schedule (at 17:00 Hrs) for the next day
If the generation schedule on certain time blocks determined by summing the requisitions of its
beneficiaries is found to be less than the minimum level of generation technically achievable by
station, the Central Generating Stations (CGS) or Inter State Generating Stations (ISGS) have the
option to go for reserve shut down, as per Regulation 6.3B of the IEGC. Such ISGS / CGS shall be
entitled to compensation for additional fuel cost towards operating below normative plant availability
factor & for multiple start / stop operations, as per provisions laid down in the IEGC.
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8.4.2. Before issuance of revision 1 schedule (at 23:00 hrs) for the next day
(a) If the dispatch schedule of the station on certain time blocks is already below the declared
capability and further surrendering of share by any beneficiary leads to a schedule that is
below the minimum level of generation technically achievable by the station, then the revision
in requisition will be accommodated as per provisions of Regulation 6.3B of IEGC.
(b) In case of surrendering of share by multiple beneficiaries received between 17:00 hrs to
22:30hrs, pro-rata approach will be adopted.
8.4.3. On the day of operation:
Surrendering of share will be considered on first-come-first-serve basis. At any stage, if the dispatch
schedule is already at the minimum level of generation technically achievable by the station, and
there is further request for surrendering of share,. the Central Generating Stations (CGS) or Inter
State Generating Stations (ISGS) have the option to go for reserve shut down, as per Regulation
6.3B of the IEGC.
8.4.4. Status of requisition
Requisition for revision received at ERLDC will remain valid till the revision of corresponding schedule
is carried out and published. Thereafter validity of the same requisition will expire and no reference of
any earlier requisition can be drawn at a later time/date.
8.4.5. Revision of schedule for upward revision of entitlement
As per present practice agreed by all constituents, in case of upward revision of entitlement, full
entitlement will be scheduled to those constituents who have already requisitioned full entitlement
previously.
In case there is already less requisition by any constituent from ISGS/s for some block, no revision of
schedule will be carried out for upward revision of entitlement for those blocks for that constituent
provided minimum level of generation technically achievable by the station criteria is satisfied. If
minimum level of generation technically achievable by the station criteria is/are not satisfied, then
ERLDC shall increase requisition of that constituent to the extent to give minimum level of generation
technically achievable by the station schedule of that ISGS. However, for those blocks where full
entitlement is requisitioned the same constituents, ERLDC will schedule full entitlement for that
constituent.
8.4.6. Revision of schedule for downward revision of entitlement
In case of downward revision of entitlement, revision of schedule will be carried out subject to
restricted entitlement. No revision will be carried out for that constituent, whose requisition is already
below entitlement previously minimum level of generation technically achievable by the station criteria
is/are satisfied and requisition is less than revised entitlement. If minimum level of generation
technically achievable by the station criteria is/are not satisfied, then ERLDC shall increase requisition
of that constituent to the extent to give minimum level of generation schedule technically achievable
by the that ISGS.
In case of subsequent upward revision of entitlement, same methodology as followed in case
of upward revision of entitlement will be followed.
For those constituents, who have given less requisition from any ISGS earlier and due to
subsequent downward revision of entitlement from same ISGS which is less than the
requisition(specially when unit trips), schedule from that ISGS will be restricted to entitlement for that
constituent and validity of earlier requisition of that constituent will expire. In case of subsequent
upward revision of entitlement from same ISGS (specially when unit returns), ERLDC will schedule
full entitlement from that ISGS to the same constituent.
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8.4.7. Scheduling of LTA and MTOA:
1. Constituent/Generator would only furnish to ERLDC the mutually agreed schedules by 17:00 Hrs
for the next day. Endorsement of the concerned SLDC/RLDC (when one of party is from outside
region) will be required.
2. ERLDC would incorporate the schedules and release the schedule for next day by 18:00 hrs.
3. SLDCs/Generators can inform of any mutually agreed changes duly endorsed by concerned
SLDC/RLDC (when one of party is from outside region) by 22:00 hrs of previous day to ERLDC.
4. Schedules for next day to be frozen by 23:00 hrs
5. Revision of the schedule during course of the day would be permitted, depending upon intimation
of the revised mutually agreed schedules duly endorsed by concerned SLDC/RLDC (when one of
party is from outside region) to ERLDC. The concerned SLDCs/RLDCs (when one of party is from
outside region) may also give standing instructions to ERLDC in advance to accommodate all day
ahead requisition/revision on the day of operation, on behalf of constituents under their jurisdiction
so that schedule furnished by other constituent/s/generator/s will be construed as mutually agreed
schedule and will be revised accordingly.
6. In case of tripping of unit of Generating station/s having LTA, schedule will be revised with
intimation to concerned SLDCs/RLDCs. The revised schedules shall become effective from the
4th time block, counting the time block in which the forced outage is declared and revision sought
in MW quantum from the generator to be the first one.
7. Revised schedules for other revision shall become effective from the 4th time block, counting the
time block in which revised mutually agreed schedule duly endorsed by concerned
SLDC/RLDC(when one of party is from outside region)has been received by ERLDC to be the first
one.
8.4.8. Scheduling of power to Bangladesh
Scheduling of power transfer to Bangladesh will be mainly coordinated between NLDC India and
NLDC Bangladesh. On the basis of ISGS availability and percentage share allocation NLDC will
prepare Bangladesh entitlement. Final schedule will be prepared considering ISGS allocation,
approved STOA and available margin. ERLDC will only implement the approved schedule by NLDC.
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Procedure, priority, timeline etc. for scheduling for all types of transactions shall be
guided by IEGC and other regulations of CERC amended time to time
8.4.9.
Revision of schedules on Unit tripping:
As per Cl 6.5.19 and 6.5.19A of IEGC, generators are to give the requisition for revision of
schedule on outage of a unit. The relevant clause is quoted below:
“Notwithstanding anything contained in Regulation 6.5(18), in case of forced outage of a unit for a Short
Term bilateral transaction, where a generator of capacity of 100 MW and above is seller, the generator
shall immediately intimate the same along with the requisition for revision of schedule and estimated time
of restoration of the unit, to SLDC/RLDC as the case may be. With the objective of not affecting the
existing contracts, the revision of schedule shall be with the consent of the buyer till 31.07.2010.
Thereafter, consent of the buyer shall not be a pre-requisite for such revision of schedule. The schedule
of the generator and the buyer shall be revised, accordingly. The revised schedules shall become
effective from the 4th time block, counting the time block in which the forced outage is declared to be the
first one. The RLDC shall inform the revised schedule to the seller and the buyer. The original schedule
shall become effective from the estimated time of restoration of the unit. However the transmission
charges as per original schedule shall continue to be paid for two days”
Also as per Cl 6.5.19A, curtailment of ST/MT/LT transactions are to be done on pro-rata basis.
The relevant clause is given below:
“In case of revision of schedule of a generating unit, the schedules of all transactions under the long-term
access, medium-term open access and short-term open access (except collective transactions through power
exchange), shall be reduced on pro-rata basis”
Accordingly, the generators/traders/sellers should intimate the curtailed figures for each
transaction/contract depicting the figures block wise. The details of methodology of pro-rata
curtailment indicating DC (old) and DC (new) should be clearly depicted in the requisition. Also at the
end, all the entities should confirm the following:
“Curtailments have been done on pro-rata basis as per Cl 6.5.19 and 6.5.19A of IEGC without preference to
any transaction/contract”.
8.4.10.
Availing of URS power by beneficiaries:
As per CERC order Dtd.11/01/10 on providing flexibility in revision of daily schedule in case of
bilateral transactions in order to facilitate utilization of un-requisitioned surplus (URS) Power to NTPC
stations, CERC has stated the following:
“We direct that all the generating stations, governed by the Tariff Regulations of the Commission be allowed to
change schedule for the unrequisitioned quantum of power from one beneficiary(s) to another beneficiary(s) of
the same power station on the requisition by these beneficiaries through the provision provided in the IEGC, i.e.
within six time blocks or as per the provisions of the IEGC as amended from time to time. In case the original
beneficiary requests back for its share of power, then its schedule and schedule of beneficiary who had availed
URS power would be revised in the six time blocks again, or as specified in the IEGC as amended from time to
time. These schedule revisions would be treated as re-allocation of power on temporary basis and would not be
taken as open access transactions”
To facilitate transaction of such URS, the beneficiary desiring the URS power shall send the URS
requisition file to the desired ISGS and subsequently the desired ISGS shall endorsed the URS
requisition of the beneficiary and should send the file to ERLDC ISGS source-wise for implementation
in the daily schedules.
In case the beneficiary is inter regional, then after receipt of the ISGS endorsed file ERLDC shall
implement the URS file subject to margin available in the desired Inter regional Path.
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8.4.11.
Down
Scheduling of Reserve Regulation Ancillary Services Regulation Up and
The ‘Ancillary Operation Service’ Procedure is issued in compliance to Regulation 14of the Central
Electricity Regulatory Commission (Ancillary Services Operations) Regulations 2015, herein after
referred to as the “AS Regulations”. The objective of AS Regulations is to help in restoring the
frequency level to the nominal level and to relieve the congestion in the transmission network.
All Generating Stations that are Regional Entities and whose tariff for the full capacity is determined
or adopted by the Central Electricity Regulatory Commission (CERC) shall provide the Reserves
Regulation Ancillary Services (RRAS Provider). National Load Despatch Center (NLDC), as the
Nodal Agency, shall be responsible for implementation of Ancillary Services at inter-state level
through the Regional Load Despatch Center (RLDCs). The Nodal Agency shall prepare merit order
stack of all RRAS Providers based on the variable cost of generation as the data provided by the RRAs
provider to respective RPCs and NLDC. The merit order stack shall be sorted from the lowest variable
cost to the highest variable cost for the purpose of implementation of the “Up Regulation” of RRAS
and shall be sorted from the highest variable cost to the lowest variable cost for the purpose of
implementation of the “Down Regulation” of RRAS. NLDC shall Trigger RRAS Regulation Up and
Regulation Down as per the system condition/ criteria mentioned in the procedure and send the file to
respective RLDC for implementation. RLDC after implementation of RRAS file within the time line
as mentioned in procedure, upload the schedule in its website and intimate the RRAS provider through
mail or over phone.
NLDC/RLDC may direct the selected RRAS Provider(s) (through RLDC) to withdraw their services
after the circumstances leading to triggering of RRAS no longer exist and in case of other reasons like
unit tripping, withdrawal of under requisition by the beneficiary etc. The time-frame for
implementation and withdrawal of service shall be determined as per the Detailed Procedure.

A virtual regional entity called “Virtual Ancillary Entity (VAE)” is created by each RLDC for
only scheduling purpose. The schedule under Ancillary for the VAE shall be deemed delivered.

For Regulation Up Service, power shall be scheduled from the RRAS Provider to the
respective VAE by the RLDC and for Regulation Down Service, power shall be scheduled
from the respective VAE to the RRAS Provider.

The schedule of the RRAS Providers will become effective earliest from the time block
starting 15 minutes after issue of the dispatch instruction by the NLDC or from any time block
as mentioned in NLDC RRAS file.

The schedule of the RRAS Provider shall be at ex-bus periphery. The injection loss (for
Regulation-UP service) and the withdrawal loss (for Regulation-DOWN service) is accounted
for in kind in the schedule of the respective VAE.

In case of downward DC revision due to unit tripping in the station of the RRAS provider, the
RRAS power shall be curtailed first, followed by STOA, MTOA and LTA transactions. RRAS
curtailment shall be effective from the second time block considering the time block in which
the intimation is received as the first time block.

In case of transmission line tripping/congestion in evacuation of power from the RRAS
provider generating station, the schedules of the respective RRAS Provider generating station
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shall be revised by the quantum scheduled by the Nodal Agency under RRAS followed by
STOA, MTOA and LTA transactions as per requirement.
Once the URS power from a RRAS provider has been scheduled under RRAS, then, this can be
recalled only by the original beneficiary in accordance with the CERC Ancillary Services Operations
Regulations 2015.In case any beneficiary other than the original beneficiary requests for URS power
from a generating station which is a RRAS provider, such request will not be considered by RLDCs if
the same URS power has already been scheduled under RRAS
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Name of the Activity: SCHEDULING FOR DAY AHEAD
START
Receive from each
ISGS Capacity
Availability in Form - A
format at 09:00hrs
ISGS Ex-pp Declare
Capacity Availability for
the following day
No
Is all applicable
DCs Received ?
Yes
% Weekly
Loss &
Share
Allocation %
Prepare ISGS Entitlement
of all constituents in
15min time blocks for the
following day - Form - B
Send Form - B to all the
beneficiary constituents at
10:00hrs (R0) & then
Subsequent revisions.
Yes
Is there any change
in ISGS DC?
DC_
Rev
No
Receive STOA
Data from OA
Dept.
Check and configure
the Advance
Approved STOAs
Receive requisition
from each
constituent in Form C format at 15:00hrs
No
ISGS & STOA
(Advance Appd)
requisitions of
Constituents
Are Requisitions of all
constituents
received?
Yes
Cont..2
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From 1
Receive Data from
NLDC at 15:00hrs
PX Transaction
Wheeling
Diversiion
Inter Regional Trx
Preparation of Constituent's Drawal
Schedule & ISGS Despatch
Schedule
Req_
Rev
Not
OK
OK
Check for Tr
Constraint, Tech
Min & Ramping
Send Drawal Schedule to
SLDCs & Despatch Schedule
to ISGS -(Form - D) for the
following day at 17:00hrs
Yes
Is there any
URS
Broadcast the URS Details to
All the Constituents & Upload
to RLDC Website
No
Receive
Data from
Grid Mgmt
Check / configure
the Day Ahead
Approved STOAs
Req_
Rev
Requisition
Change
Is there any change in
ISGS DC or
Constituent’s
Requisition?
DC_Rev
DC Change
No
Preparation of
Constituent's Drawal
Schedule & ISGS
Despatch Schedule
Send final Drawal Schedule to
SLDCs & Despatch Schedule
to ISGS -(Form - D) for the
following day at 23:00hrs
Is there any URS Power?
END
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Activity: REVISION OF CURRENT DAY SCHEDULE
START
No
Is there any
Change in DC of
ISGS?
RR
Yes
Receive the revised
of ISGS Capacity
Availability in Form A format
Receive Revised
Declaration of
Available Capacity
of ISGS
Yes
No
Prepare ISGS
Entitlement of
all constituents
in 15min time
blocks w.e.f 6th
time block Form - B
Is it due to
forced
outage of
Unit?
Send From - B
to all the
beneficiary
constituents
Send From - B to
all the beneficiary
constituents
Receive Revised
Requisition from the
Beneficiary
Constituents
Receive
requisition from
constituent in
Form - C format
Prepare ISGS
Entitlement of
all constituents
in 15min time
blocks w.e.f 4th
time block Form - B
Preparation of
Constituent's Drawal
Schedule & ISGS
Despatch Schedule
Not
OK
OK
Send Drawal Schedule to SLDCs
& Despatch Schedule to ISGS.
(Form - D)& upload to web
Check for Tr
Constraint, Tech
Min & Ramping
Yes
Is there any
URS Power?
Broadcast the URS Details to All the
Constituents and Upload to RLDC
website
END
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Activity: Procedure flow chart for current day schedule revision…contd
RR
Yes
Is it NEW Approval of Same Day STOA?
No
Yes
Is there any System Constraint?
No
END
No
Is SLDC Changed
its Requisition?
Yes
Receive the revised
Requisition of the
Beneficiary Constituent
in Form - C format
Receive Revised
Requisition of
Beneficiary
Constituent
Preparation of Constituent's
Drawal Schedule & ISGS
Despatch Schedule w.e.f 6th
time block or latter as approved
/ requisitioned
Preparation of Constituent's
Drawal Schedule & ISGS
Despatch Schedule w.e.f 4th
time block
Send Drawal Schedule to
SLDCs & Despatch Schedule
to ISGS -(Form - D)
Yes
Check for Tr
Constraint, Tech
Min & Ramping
Yes
Check for Tr
Constraint, Tech
Min & Ramping
No
No
Is there any URS Power?
No
Yes
Broadcast the URS Details to All the
constituents & Upload to RLDC website
END
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Activity: IMPLEMENTED SCHEDULE
START
Regional Weekly Loss %
State System Loss %
Are Loss % Values
entered correctly?
Correct the values as applicable
for the particular day
No
Yes
Are Loss % Values
entered correctly?
Share Allocation %
No
Correct the values as applicable
for the particular day
Yes
STOA Details
(Advance Approved &
Day Ahead Approvals)
No
Are STOAs
Configured correctly?
Correct the values as applicable
for the particular day
Yes
Details of Grid Incidents
and Grid Disturbance if
any.
No
Was the Schedule
Revision done
correctly?
Correct the values as per
Declaration in line to IEGC
provisions
Yes
Details of Transmission
Constraints, if any.
No
Was the
curtailment done
correctly?
Incorporate the curtailment
with correct values as per
IEGC guidelines / provisions
Yes
Details of Revisions in
Declared Capacity of
ISGS & Requirements of
Constituents
Was all the
Revisions
scheduled
correctly?
No
Check for the Constituent's Drawal
Schedule & ISGS Despatch Schedule
& co-ordinate for rectification of errors
if any.
Yes
Cont..2
50 | P a g e
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From
1
Inter Regional Link
Schedules
(STOA & Wheeling /
Diversion Details)
Check for matching of the Inter Regional
Schedules for each link.
Are the Inter Regional
Link Schedules are
matching with other
Region?
No
Co-ordinate with
respective RLDCs &
eliminate the
discrepancy.
Yes
Communicate to
respective RLDC
Release the Final Implemented
Schedule and Upload in to Web.
Receive from SLDC /
ISGS / Traders /
RLDCs
Is there any
dispute on
discrepancy of
the Schedule,
with in 5 days?
Go to Start
Yes
No
Release weekly schedules to commercial
dept for Energy Accounting
END
51 | P a g e
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Chapter 9
9.
SCADA System Operation
9.1.
Introduction
For over all development of Load Despatch & Communication facilities in Control Centers, a Unified
Load Despatch Scheme (ULDC) in ER has been commissioned in September, 2005. The scheme
envisaged installation and commissioning of Remote Terminal Units with dedicated communication
system comprising of Fibre Optic and PLCC system, installation and commissioning of Auxiliary
Power Supply system such as UPS, DG set. Regional Load despech Center Established at Kolkata
whereas State Load Despatch Centres (SLDCs) were established at Howrah (West Bengal), Maithon
(DVC), Patna (Bihar), Ranchi (Jharkhand), Bhubaneswar (Odisha) and Sikkim (Sikkim) along with
Sub-LDCs were also established. ULDC scheme operates in a hierarchal structure consisting of State
of Art equipment’s and advanced EMS-SCADA functions.
9.2.
Energy Management System
Energy Management system (EMS) modules implemented in the different control centers (RLDC/
SLDCs) consists of various applications covering wide spectrum of functions like Pre-dispatch, Real
time dispatch and Post-dispatch functions. The Energy Management System (EMS) tools such as
state estimation, contingent analysis, optimum power flow, load forecasting, resources scheduling
and commitment has provided system operators greater flexibility in taking appropriate and judicious
decisions during the course of operation. To supplement further, other tools such as State Estimator
(SE), Network Topology Processor (NPT) and Contingency analysis (CA)
9.3.
Communication System
A strong Communication Backbone network is the key to the smooth functioning of the ULDC
Scheme. Keeping this in view; a dedicated communication has also been established under ULDC
scheme consisting of Fibre-Optic & Power Line Carrier. Communication (for the end link data flow). in
order to provide reliability and redundancy in data communication channel, an alternate physical route
between ERLDC & SLDCs has been established.
9.4.
SCADA Features
Under this scheme more than 40000 numbers of Analog measurands (consisting of MW, MVAR,
AMP, KV, FREQ, OLTC tap position) and Status Indication points (consisting of ISO, CB, SOE) have
been wired up covering more than 460 nodes across the Eastern Region. Data from these nodes are
updated every 10-15 seconds for analog measured and status point indication with the change of
state.
9.5.
Operational Requirements
9.5.1. Validation/Correctness of Data
The entire EMS functions and real time monitoring of the regional grid depends upon the
availability, reliability and validity of the tele-metered data.
It is therefore, utmost essential that the various control centers viz. RLDC / SLDCs / SubLDCs take responsibility towards correctness/ validation of the data on a regular basis so that
the facilities created in this scheme is optimally utilized to benefit the grid operation.
9.5.2. Availability of Speech and Data Communication System:
In the event of commissioning of a new Generating station / sub-station / transmission
element etc., it is essential that reliable and efficient speech & data communication systems
are provided by the concerned agency to facilitate data flow up to ERLDC / SLDC. as the case
52 | P a g e
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may be prior to commence the commercial operation. In this connection, Clause 4.6.2 of
Indian Electricity Grid Code is relevant and the same is reproduced below.
Quote
“Reliable and efficient speech and data communication systems shall be provided to facilitate
necessary communication and data exchange, and supervision/control of the grid by the RLDC,
under normal and abnormal conditions. All Users, STUs and CTU shall provide Systems to telemeter
power system parameter such as flow, voltage and status of switches/ transformer taps etc. in line
with interface requirements and other guideline made available by RLDC. The associated
communication system to facilitate data flow up to appropriate data collection point on CTU’s system,
shall also be established by the concerned User or STU as specified by CTU in the Connection
Agreement. All Users / STUs in coordination with CTU shall provide the required facilities at their
respective ends as specified in the Connection Agreement.”
Unquote
9.5.3. Availability of RTUs
Remote Terminal Units (RTUs) constitute an important element of the SCADA system for
transfer of analog measurands and status indications continuously from various nodes to the
control centers. Hence, it is essential that RTUs installed in the system and reporting to the
different control centers are monitored and maintained in a proper way to ensure continuity of
data to the control centers for the operational purpose. Failure of any RTU may cause
stoppage of data to the control centers and thereby may cause operational problem. As such,
RTU needs utmost attention and any problem encountered in RTU causing failure of data to
the control centers is required to be attended at the earliest preferably within 24 hours so that
information from the defective RTU is restored to the respective control centers to avoid any
operational problem.
9.5.4. Availability of Dedicated Communication System
In order to transfer the real time data from RTUs to Sub-LDCs / SLDCs / SRLDC
communication back bone network consisting of Fibre Optic and PLCC end links etc. are
provided and the same need to be maintained properly. Further in case of any failure of the
link viz. fibre cut between two locations causing complete failure of upstream data, failure of
supply to the repeater station etc. an immediate action is initiated by the concerned agency to
restore the system data as quickly as possible preferably within 24 hours to avoid any
operational problem.
9.5.5. Upkeep / Maintenance of Control Centers
Efforts should be made by SRLDC / SLDCs / Sub-LDCs to ensure that proper environmental
conditions are maintained in all the control centers for proper functioning of the equipments
and in the event of failure of any auxiliary systems such as Air Conditioning, UPS etc.,
immediate action is initiated by the concerned to restore the system at the earliest.
53 | P a g e
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Chapter 10
10. Metering and Settlement System
10.0 Introduction
The settlement system is an important part in implementation of Availability Based Tariff (ABT) . The
system involves metering, data collection and processing, energy accounting and raising of bills of
the constituents. This chapter indicates the roles and responsibilities of the different regional entities
in making the settlement system operative in most efficient manner.
10.1
Metering and Data Collection
10.1.1 As per Chapter-6 clause 6.4.21 of IEGC, the CTU shall install Special Energy Meters on all
inter connections between the regional entities and other identified points for recording of
actual net MWh inter-changes, average frequency on 15-minute time block and MVARh
drawls under low/high voltage conditions.
10.1.2 The type of meters to be installed, metering scheme, metering capability, testing and
calibration requirements and scheme for collection and dissemination of meter data shall be
as per Annexure-2 of IEGC.
10.1.3 All concerned entities having SEMs installed in their premises shall fully cooperate and extend
necessary assistance by taking weekly meter reading and transmitting them to ERLDC in time.
10.1.4 All concerned entities having SEMs shall also carry out necessary time adjustments in the
meter as per the procedure already in vogue/advice of
10.1.5 In the event of any reported problem of SEMs as by ERLDC during processing in the matter
shall be reported to concerned / to the owner of the meter for necessary replacement /repair.
10.2
Automated Meter Reading (AMR)
The intent of AMR scheme is to automate the task of data collection from each
meter/location periodically and storing the same in a database. Data from the database is be
used by application software such as ABT energy accounting software and further processing.
GPRS based energy meter data collection is beneficial for both the constituents and Load
despatcher. AMR system solve the problem of manual meter data downloading from the remote
locations resulting in timely data receipt by Regional Load Despatch Centre as well as
submission of processed data to Regional Power Committee. In Eastern Region, SEM data from
some remote locations was not being received due to DCD error and other system complicacies
which are normalised after implementation of AMR system and ERLDC started receiving data on
regular basis. Total 655 nos of SEM out of 875 nos are connected with DCU in Eastern Region
and all DCUs are reporting to Central Data Collection System (CDCS) at ERLDC.
10.3
Data Processing
10.3.1 As mentioned in section 6.4.21, all the energy meter data would reach ERLDC by every
Tuesday afternoon via email. The CTU/STU, ISGSs and regional entities shall be responsible
for sending of data of sending of data to ERLDC. ERLDC would carry out data validation and
in case of any problem, request any entity to send the data again. Each entity would therefore
have necessary backup of data at their local PC level.
10.3.2 The computation of the net injection of each ISGS and actual net drawl of each beneficiary
shall be carried out in line with clause 6.4.22 of IEGC based on the above meter readings
received at ERLDC. The preparation and issue of REA to the constituents shall be done by
ERPC Secretariat on the basis of meter data and implemented schedule forwarded by ERLDC.
54 | P a g e
ERLDC: POSOCO
10.3.3 Data related to the reactive energy exchange between two STU systems and between STU
and ISTS points would also be forwarded by ERLDC for preparation of reactive energy
accounts and communication to all constituent and ERLDC by ERPC Secretariat.
10.3.4 The final schedule implemented by ERLDC shall be open to all regional entities for checking /
verification for a period of five days and mistakes/omissions ,if any ,would be rectified.
10.3.1 Energy Accounting
ERPC Secretariat would process the information provided by ERLDC and other utilities to determine
the following energy accounts:
10.3.1.1
Monthly Regional Energy Account for the purpose of billing
a)
Capacity charges payable by each beneficiary to each ISGS.
b)
Energy charges payable by each beneficiary to each ISGS
c)
ISGS energy scheduled for each regional beneficiaries.
In case of utilities outside Eastern regions are having shares on ISGSs, ERLDC shall be
furnishing consolidated schedule drawal at the concerned regional boundary/ies only.
10.3.1.2
`
Weekly Deviation Account
Weekly Deviation charges shall be settled as per deviation calculation for each 15 minute
block. The deviation charges payable/receivable shall be calculated with respect to deviation
Pool. The Pool Account shall be maintained by ERLDC. The deviation account as prepared by
ERPC Secretariat shall have the following components
a)
Deviation charges payable by beneficiaries/ISGSs/IPPs to Pool
b)
Deviation charges receivable by the beneficiaries/ISGSs/IPPs from the pool
c)
Additional Deviation charges payable by beneficiaries/ISGSs/IPPs to Pool
d)
Pool balance amount due to capping of deviation rate for Thermal ISGSs.
Since the hydro stations within Bhutan System is not covered under deviation settlement
mechanism, the accounting for drawal from these stations shall be as per the Monthly energy
account as per the agreed principles. However, deviations of injections from these stations
shall be accounted for and duly apportioning the deviations amongst its beneficiaries.
10.3.1.3
Weekly VARh Account
The VARh account as prepared by ERPC Secretariat shall have two distinct components.
a)
VARh charges payable/receivable for VARh exchange between STU systems
b)
VARh charges payable by Beneficiaries for low VARh drawal or High VARh injection
between STU and ISTS points.
The VARh account for low VARh drawal and High VARh injection between STU ans ISTSs
shall be maintained by ERLDC. Any payment to be made from VARh account shall be
discussed beforehand in ERPC forum.
10.3.1.4
Congestion Charge Account
The Congestion Charge account is prepared by ERPC secretariat. There is a congestion
imposed on real time Grid Operation, Congestion Charge shall be applicable to Regional entities as
per the CERC (Measures to relieve congestion in real time operation) Regulations and orders on rate
of congestion charge as applicable from time to time. Congestion charge would be levied for over
drawal or under-injection in the importing control area and, Congestion charge would also be levied
for under drawal or over-injection in the exporting control area.
55 | P a g e
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10.3.2 Pool Account Operation
In line with Annexure-I of IEGC, from the date of issue of weekly deviation account and Reactive
Energy Charge Account by ERPC Secretariat, within 10-days, the concerned regional entity shall
pay on priority the indicated amount into regional deviation, Reactive Energy and Congestion
charges accounts operated by ERLDC. The agencies that have to receive the money from pool
accounts would then be paid within 2 working days. These pool accounts are to be reconciled once in
periodic intervals (i.e quarterly) and reconciliation statement is uploaded at ERLDC Website.
56 | P a g e
ERLDC: POSOCO
Annexure: I Generation capacities in Eastern Region
57 | P a g e
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Annexure: II List of Generating Units and their Capacities
(As on 30.06.16)
CAPACITY DETAILS
BSPGCL
BSEB SYSTEM
& BSPHCL
STATION
THERMAL
INS CAP
EFF CAP
UNITS
TOTAL
UNITS
BARAUNI
2x110
220
2x105
210
MUZAFFARPUR
2x110
220
2x110
220
TOTAL
HYDRO
440
KOSI
DEHRI ( BHPC )
OTHERS
TOTAL
430
4x5
20
4x5
20
7x1.65
11.6
7x1.65
11.6
13.3
13.3
13.3
13.3
TOTAL HYDRO
GRAND TOTAL
ALL FIGURES IN M W
THERMAL+HYDRO
24.9
24.9
464.9
454.9
JUUNL
JSEB SYSTEM
& TVNL
STATION
INS CAP
UNITS
THERMAL
TVNL
PATRATU
TENUGHAT
4x50+2x100+
4x110
2x210
TOTAL
HYDRO
UNITS
4x40+2x90+
2x105+2x110
420
2x210
1260
SUBERNREKHA
2x65
130
2x65
2X5
10
2X5
THERMAL+HYDRO
TOTAL
770
420
1190
SIKIDIRI
TOTAL HYDRO
GRAND TOTAL
EFF CAP
TOTAL
840
130
10
140
140
1400
1330
D V C SYSTEM
STATION
THERMAL
INS CAP
UNITS
TOTAL
EFF CAP
UNITS
TOTAL
BOKARO'B'
WARIA TPS
CTPS 'A'
CTPS 'B'
MEZIA
MEZIA 'B'
DSTPS
DTPS
KODERMA TPS
RTPS
3x210
1x140+1x210
3x140
2x250
4X210+2x250
2x500
2x500
1X140+1X210
2x500
2X600
630
350
420
500
1340
1000
1000
350
1000
1200
7790
3x210
1x140+1x210
3x130
2x250
4X210+2x250
2x500
2x500
1X140+1X210
2x500
2X600
630
350
390
500
1340
1000
1000
350
1000
1200
7760
MAITHON
PANCHET
TILAYA
2X20+1x23.2
2x40
2x2
63.2
80
4
147.2
7937.2
2X20+1x23.2
2x40
2x2
63.2
80
4
147.2
7907.2
TOTAL
GAS TURBINE
HYDRO
TOTAL
GRAND TOTAL
TH+ HY + GT
58 | P a g e
ERLDC: POSOCO
CAPACITY DETAILS
OPGC & OHPC
STATION
THERMAL
INS CAP
UNITS
TALCHER (NTPC)
STAGE-I
STAGE-II
BURLA
CHIPLIMA
BALIMELA
RENGALI
U.KOLAB
U.INDRAVATI
MACHKUND
TOTAL HYDRO
OPGC
GRAND TOTAL
IB VALLEY
THERMAL+HYDRO
TOTAL
4x60
2x110
250
220
470
4x60
2x110
240
220
460
2x49.5+3x37.5
+2x32
3x24
2X75+6x60
5x50
4x80
4x150
3X17+ 3X21.5
275.5
2x49.5+3x37.5
+2x32
3x24
2X75+6x60
5x50
4x80
4x150
3X17+ 3X21.5
275.5
TOTAL
HYDRO(OHPC)
TOTAL
ALL FIGURES IN M W
EFF CAP
UNITS
2x210
72
510
250
320
600
57.37
2084.9
420
2974.9
2x210
72
510
250
320
600
57.37
2084.87
420
2964.87
WEST BENGAL SYSTEM
STATION
INS CAP
UNITS
TOTAL
EFF CAP
UNITS
TOTAL
THERMAL
WBPDCL
BANDEL
SANTALDIH
KOLAGHAT
BAKRESWAR
SAGARDIGHI
DPL
DPPS
4x82.5+1x210
2X250
6x210
5x210
2 x 300
3x75+1x110+1X300+
1X250
TOTAL
HYDRO
(WBSEDCL)
540
500
1260
1050
600
885
4x60+1x210
2X250
6x210
5x210
2 x 300
1x70+2x75+1x110+1X
300 + 1X250
4835
JALDHAKA-I
JALDHAKA-II
MASSANJORE
RAMAM
TISTA
TLDP
MICRO HYDEL
PPSP
4x9
2x4
2x2
4x12.5
9X7.5
4X33
TITAGARH
N.COSSIPORE
SOUTHERN
BUDGE-BUDGE
450
500
1260
1050
600
880
4740
36
8
4
50
67.5
132
7.51
900
1205.0
4x9
2x4
2x2
4x12.5
9X7.5
4X33
4x60
2x30+2x50
2x67.5
3X250
240
160
135
750
1285
4x60
100
2x67.5
3X250
240
100
135
750
1225
2X300
600
2X300
600
4X225
TOTAL HYDRO
4X225
36
8
4
50
67.5
132
6.19
900
1203.7
GAS TURBINE
TOTAL G.T.
CESC
THERMAL
TOTAL
Haldia Energy Ltd
((Thermal))
Haldia TPS
GRAND TOTAL
THERMAL+HY+GT
7925
7769
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CAPACITY DETAILS
SIKKIM SYSTEM
SYSTEM
SIKKIM
STATION
INS CAP
UNITS
HYDRO
DIESEL
TOTAL
TOTAL
32.89
5
37.89
ALL FIGURES IN M W
EFF CAP
UNITS
TOTAL
32.89
5
37.89
CENTRAL SECTOR
SYSTEM
THERMAL
STATION
FARAKKA STG-I & II
FARAKKA STG-III
KAHALGAON STG-I
KAHALGAON STG-II
NTPC
HYDRO: NHPC
BHUTAN (DGPC) :
HYDRO
CHPC
KHPC
BHPC
DHPC
THPC
INS CAP
UNITS
3x200+2x500
1x500
TOTAL
1600
500
EFF CAP
UNITS
3x200+2x500
1x500
TOTAL
1600
500
4X210
3x500
840
1500
4X210
3x500
840
1500
TALCHAR STG-I
TALCHAR STG-II *
BARH STG-II
NABINAGAR
TOTAL NTPC
2X500
4X500
2X660
1 X 250
1000
2000
1320
250
9010
2X500
4X500
2X660
1 X 250
1000
2000
1320
250
9010
RANGIT
TEESTA V
TOTAL NHPC
3 x 20
3 x 170
60
510
570
3 x 20
3 x 170
60
510
570
4x84
4 x 15
2 X 20 +2 X12
2X63
6 x 170
336
60
64
126
1020
1606
4x84
4 x 15
2 X 20 +2 X12
2X63
6 x 170
336
60
64
126
1020
1606
CHUKHA CHPC
KURICHU HEP
BASOCHHU HEP
DAGACHHU HEP
TALA HEP
TOTAL
IPP/MPP
SYSTEM
THERMAL
VEDANTA
APNRL
GMR
TATA
JINDAL
IND BHARAT
HYDRO
GATI
DANS GROUP
STATION
INS CAP
UNITS
TOTAL
EFF CAP
UNITS
TOTAL
STERLITE*
ADHUNIK
GKEL*
MPL
JITPL
IBEUL
SUB-TOTAL
4x600
2 X270
3X350
2x525
2x600
2 X350
2400
540
1050
1050
1200
700
6940
4x600
2 X270
3X350
2x525
2x600
2 X350
2400
540
1050
1050
1200
700
6940
CHUJACHEN
JORETHANG HEP
SUB-TOTAL
2X55
2 X 48
110
96
206
7146
206
2X55
2 X 48
110
96
206
7146
Total
* One unit each of Sterlite and GKEL is dedicated to Odisha
EASTERN REGION
SYSTEM
STATION
INS CAP
EFF CAP
TOTAL
TOTAL
33050
32775
THERMAL
5
5
DIESEL
6021
6022
E.REGION
HYDRO
0
0
GT
38801
TOTAL
39077
Talcher Stage-II ( I.C 2000 MW) is dedicated to SR. Only 10% share is allocated to GRIDCO.
60 | P a g e
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Annexure :III
Captive Power Stations in Eastern Region and Their Capacities
CAPTIVE POWER STATIONS IN EASTERN REGION
AS ON 30.05.2016
POWER SATION
SYSTEM
ODISHA
BIHAR
JHARKHAND
W.BENGAL
COAL
INDIA LTD
REGION
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
1
2
3
1
2
3
4
5
6
7
8
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
1
2
3
4
VENDANTA (JHARSUGUDA)
NALCO (ANGUL)
JINDAL STEEL & POWER LTD., ANGUL
BHUSAN STEEL & STRIPS (M'MUNDALI)
BHUSAN STEEL, JHARSUGUDA
HPCL(HINDALCO), HIRAKUD
JINDAL STAINLESS LTD., DUBURI
IMFA (CHOUDWAR)
RSP(ROURKELA)
IFFCO (PARADEEP)
NBVL (MERAMUNDALI)
VEDANTA (LANJIGARH)
ARATI STEEL (GHANTIKHAL, CUTTACK)
ACTION ISPAT & POWER PVT. LTD.
VISA STEEL LTD. (NEW DUBURI)
KMCL(NINL), Duburi
OCL INDIA LTD., RAJGANGPUR
M/S FACOR POWER LIMITED
SMC POWER GEN. LTD.
SREE GANESH
SHYAM DRI( PANDOL, SAMBALPUR)
ACC, BARGARH
MAITHON ISPAT NIGAM LTD., JAIPUR RD.
TATA SPONGEIRON( JODA )
MSP METALLICS LTD.
ORISSA SPONGE IRON & STEEL LTD
EMAMI PAPER MILLS LTD.
RSPL (KATAPALLI)
ARYAN ISPAT & POWER PVT. LTD.
PATTANAIK STEEL (KEONJHAR)
MAHAVIR FERRO ALLOYS PVT. LTD.
DINABANDHU / YAZDANI STEEL & POWER
SEVEN STAR STEELS LTD.
NARBHERAM POWER & STEEL PVT. LTD.
TOTAL
FCI
USHA MARTIN
BCCL REHLA
TOTAL
JOJOBERA
BSL
TISCO
(EXCL. DG SETS)
BIHAR CAUSTIC & CHICAL LTD
USHA MARTIN LTD., JAMSHEDPUR
USHA MARTIN LTD., RANCHI
ABCIL, GARHWA
TOTAL
DSP
TATA POWER HALDIA
HALDIA REFINERY (IOC )
HALDIA PETROCHEMICALS LTD.
IISCO
CRESCENT POWER
BEL
PCBL, DURGAPUR
RAM SWARUP LOHIA UDYOG
RENUKA SUGAR
DPSCO
ELECTRO STEEL GREEN POWER.
HIMADRI CHEMICAL
CORPORATE ISPAT ALLOY
AMRITA BIO-ENERGY & IND. LTD.
KPL (BIOMASS)
SIIPL (SOLAR)
KESORAM REYON
KAMARHATI BIOGAS LTD
TOTAL
ECL
BCCL
CCL
NEC
TOTAL
TOTAL
INSTALLED CAPACITY
(MW)
9X135
10 X120
4X135
1X33+1X77+2X150
1X40+1X60+2X130+2X8
3 X 100+1X67.5
2X125+1X13
2X54+1X30+2X60
4X25+2X60
2 X 55
1X30+1X65
3 X 30
1X40+1X50
1X25+1X12+1X43
3X25
2X19.25+1X24
2X27
1x45
1X8+1X25
1X32
1X30
1X30
1X30
1X18.5+1X7.5
1X25
1X24
1X15+1X5
1X20
1X18
1X15
1X12
1X10
1X8
1X8
80
25
1X30
2X120 + 67.5
2X55+3X60+1X12
1X67.5+3X30+1X25
1X12.5+1X20
35X1+30X2+25X1+15X1
10X2
30X2
2X60+4X5
(2X45+1X30)
2X10+2X20
( 2X20)
(1x40)
( 1X30)
( 1X15)
(4x3)
(1x12)
(1X10)
10
( 1X6)
TOTAL
(MW)
1215
1200
540
410
376
367.5
263
258
220
110
95
90
90
80
75
62.5
54
45
33
32
30
30
30
26
25
24
20
20
18
15
12
10
8
8
5892.00
80
25
30
135
307.5
302
215
30
135
20
60
1070
140
120
84.5
75.5
60
40
40
30
20
15
14.2
12
12
10
10
6
5
6
6
706.2
20
49.6
70.3
1
140.9
7944
61 | P a g e
ERLDC: POSOCO
Annexure: IV
Deviation rate at different frequencies
62 | P a g e
ERLDC: POSOCO
Annexure: V
Format message for violation of IEGC
EASTERN REGIONAL LOAD DESPATCH CENTRE
POWER SYSTEM OPERATION CORPORATION LIMITED
14, GOLF CLUB ROAD, TOLLYGUNJ, KOLKATA-700033
Tel.: 033-24235265/5875, FAX: 033-24235809/5704, www.erldc.org
Message No Non‐Compliance Message Type
Emergency
Date
Alert
From:‐Shift‐In‐Charge, ERLDC, Kolkata To WBSEB OPTCL DVC
JSEB
Copy To Sub : Violation of Indian Electricity Grid Code
Type of Violation Category of IEGC Clause
Violation Frequency Violation Voltage Violation 5.2(m)
Loading Violation Zero Crossing Violation Deviation Violation 5.2(s) 6.4.12 6.6.3 6.6.6 6.4.12
6.4.6 Special Events Regional Entity EMERGENCY Drawal / Injection Schedule (MW) Time (HH:MM)
BSPHCL Details 5.4.2(a) 5.4.2(b) 6.4.6 6.4.7 6.4.10 6.4.12 Actual Drawal / Injection (MW) Actual Deviation (MW) Area Control Error (MW) Desired Drawl/ Injection (MW) You are requested to take immediate action to strictly adhere to desired drawl/generation as mentioned above and take immediate actions to remove the violation for reliable and secure system operation. Non‐compliance of the RLDC direction would be a threat to grid security and shall be treated as violation of CERC Regulations / CEA Grid Standards / Electricity Act, 2003. The same would be reported to CERC as per Cl.1.5 of IEGC, 2010 and amendments thereof. Shift-In-Charge
Eastern Regional Load Despatch Centre
63 | P a g e
ERLDC: POSOCO
Annexure: VI List of 765/400kV & 400/220kV ICTs and their tap Positions
ICT TAP POSITION
TAP POSITION OF 765/400 kV & 400/220 kV ICTS IN EASTERN REGION AS ON 30.06.16
SUBSTATION
CAPACITY
TAP
GAYA 765/400 kV
SASARAM 765/400 kV
NEW RANCHI 765/400 kV
ANGUL
JHARSUGUDA
BINAGURI
NEW PURNEA
MUZAFFARPUR
MALDA
SASARAM 400/220kV
BIHARSHARIF
BIDHANNAGAR
PATNA
FARAKKA STPS
MAITHON
RANCHI
JAMSHEDPUR
PARULIA
BAKRESWAR
ARAMBAGH
JEERAT
KHARAGPUR
SUBHASGRAM
KOLAGHAT
BARIPADA
RENGALI
ROURKELA
TALCHER STPS
MERAMUNDALI
N. DUBURI
U. INDRAVATI HEP
JEYPORE
MENDASAL
BOLANGIR
CHAIBASA
KEONJHAR
RANGPO
GAYA 400/220 kV
3x1500
1x1500
2x1500
2X1500
2X1500
2X315
2X315
2X315
2X315
2X315
3X315
1X315
2X315
1X315
2X315
2X315
2X315
2X315
2X315
4X315
4X315
2X315
4X315+ 1X 500
2X315
2X315
2X315
2X315
2X315
2X315
2X315
2X315
2X315
2X315
2X315
2X315
2X315
5X315
1X315 + 1x500
12
14
12
12
12
10
11
12
12
12
12
9B
11
11
9B
9B
15
9
11
13
11
7
9
12
9
12
10
13
10
9
9B
14
6, 9
9B
9B
9B
9
12
FOR 765/400 kV TAP 1:807/400, 12:765/400, 23: 723/400
FOR 400/220 KV ICT TAP 1: 440/220, 9:400/220, 17:360/220
64 | P a g e
ERLDC: POSOCO
Annexure: VII
Reactive Compensation Details
LENGTH
Sl No
LINE/SUB-STN
REACTORS CAPACITY
IN MVAR
( KM )
LINE
1
2
BEHRAMPUR-JEERAT
SAGARDIGHI-SUBASHGRAM
200
256.3
3
4
5
6
7
8
9
11
12
14
15
16
FARAKKA-PARULIA-I
BIDHANAGAR-PARULIA I
LAKHISARAI-B'SHARIFF-I
LAKHISARAI-B'SHARIFF-II
K'GAON-MAITHON-I
K'GAON-MAITHON-II
ROURKELLA-CHAIBASA-I
ROURKELA-TALCHER I
ROURKELA-TALCHER II
ROURKELA- JAMSHEDPUR-II
KEONJHAR-BARIPADA
BARIPADA-MENDASAL-II
150
11
89
89
172
172
120
175
175
17
18
19
BAKRESWAR-ARAMBAGH
BAKRESWAR-JEERAT
RENGALI-INDRAVATI
132
162
356
20
21
22
23
24
25
26
27
28
29
32
B'SHARIFF-TENUGHAT
MALDA-PURNEA -I
MALDA-PURNEA -II
BINAGURI-BONGAIGAON-I
BINAGURI-BONGAIGAON-II
BINAGURI-BONGAIGAON-III
BINAGURI-BONGAIGAON-IV
BINAGURI-TALA-I
BINAGURI-TALA-II
BINAGURI-TALA-IV
PURNEA-MUZAFFARPUR-I
180
167
167
216
216
224
224
115
115
98
240
33
PURNEA-MUZAFFARPUR-II
240
34
35
36
37
38
ROURKELA-JHARSUGUDA- I
ROURKELA-STERLITE-I
MERAMUNDALI-ANGUL-I
ANGUL-BOLANGIR
BOLANGIR-JEYPORE
142
113
20.8
199
288
39
40
41
42
43
44
45
46
47
48
B'SHARIFF-PUSAULI -I
PUSAULI-ALLAHABAD
PUSAULI-SARNATH
MUZAFFARPUR-GRKPR-I
MUZAFFARPUR-GRKPR-II
B'SHARIFF-BALIA -I
B'SHARIFF-BALIA -II
PATNA-BALIA-III
PATNA-BALIA-IV
RANCHI-SIPAT-I
195
271
49
RANCHI-SIPAT-II
405
50
51
52
JEYPORE-GAJUWAKA-I
JEYPORE-GAJUWAKA-II
MPL-RANCHI -I
220
220
188
53
MPL-RANCHI -II
188
54
55
56
PUSAULI-BIHARSHARIFF-I
PUSAULI-BIHARSHARIFF-II
765 kV PUSAULI-FATHEPUR
198
198
356
57
765 kV RANCHI-DHRAMJAYGARH I
303
58
765 kV RANCHI-DHRAMJAYGARH II
303
59
60
61
LAKHISARAI-KhSTPP - I
LAKHISARAI-KhSTPP - II
PATNA - KISHANGUNJ-I
145
145
352
62
PATNA - KISHANGUNJ-II
352
63
MAITHON-GAYA-I
235
64
MAITHON-GAYA-II
235
65
66
67
68
69
70
71
72
73
74
MAITHON-MEJIA-I
BANKA-BIHARSARIFF I & II
BARIPADA-KEONJHAR
BIHARSARIFF-PURNEA I
BIHARSARIFF-PURNEA II
BIHARSARIFF-VARANASI-I
BIHARSARIFF-VARANASI-II
PURNEA- BINAGURI-I
PURNEA- KISHANGANJ-I
765 KV GAYA- BALIA
83
185
156
232
232
321
321
168
71
120
75
76
77
765 KV GAYA- VARANASI-I
766 KV GAYA- VARANASI-II
765 KV JHARSUGUDA-ANGUL I
272
272
273
78
765 KV JHARSUGUDA-ANGUL II
273
79
80
764 KV JHARSUGUDA-DHARAMJAYGARH-I
765 KV JHARSUGUDA-DHARAMJAYGARH- II
151
151
TOTAL
156
273
260
260
242
242
185
185
405
REMARKS
END
1X50
1X63
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1 X 63
1 X 63
1X63
1X63
1x50
1x50
1x50
1x63
1x63
1X63
1X63
1X80
1X80
1X63
1X63
1X63
1x63
1x63
1x63
1x63
1x63
1X63
1x80
1x50
1x50
1x80
1X50
1X63
1X63
1X63
1X50
1X50
1X50
1X63
1X63
1X80
1X80
1X80
1X80
1X80
1X80
1 X50
1 X50
1 X50
1 X50
1 X63
1 X63
1 X 330 #
1 X 330 #
1 X 240 #
1 X 330 #
1 X 240 #
1 X 330 #
1 X 50
1 X 50
1 X 63
1 X 63
1 X 63
1 X 63
1 X 50
1 X 50
1 X 50
1 X 50
1 X 50
2 X 50
1 X 50
1 X 80
1 X 80
1 X 50
1 X 50
1 X 63
1 X 63
1 X 240 #
1 X 330 #
1 X 240 #
2 X 240 #
1 X 240 #
1 X 240 #
1 X 240 #
1 X 240 #
1 X 330 #
1 X 330 #
JEERAT
SAGARDIGHI
SUBHASGRM
FARAKKA
PARULIA
B'SHARIFF
B'SHARIFF
MAITHON
MAITHON
ROURKELA
TSTPP
TSTPP
ROURKELA
BARIPADA
MENDASAL
BARIPADA
BAKRESWAR
JEERAT
RENGALI
INDRAVATI
TENUGHAT
MALDA
MALDA
BONGAIGAON
BONGAIGAON
BINAGURI
BINAGURI
BINAGURI
BINAGURI
BINAGURI
PURNEA
MZFRPR
PURNEA
MZFRPR
ROURKELA
ROURKELA
MERAMUNDALI
BOLANGIR
BOLANGIR
JEYPORE
BIHARSARIFF
PUSAULI
PUSAULI
MUZAFFARPUR
MUZAFFARPUR
BALIA
BALIA
BALIA
BALIA
RANCHI
SIPAT
RANCHI
SIPAT
GAJUWAKA
GAJUWAKA
MPL
RANCHI
MPL
RANCHI
PUSAULI
PUSAULI
PUSAULI
FATHEPUR
RANCHI
DHARAMJAYGARH
RANCHI
DHARAMJAYGARH
LAKHISARAI
LAKHISARAI
PATNA
KISHANGANJ
PATNA
KISHANGANJ
GAYA
MAITHON
GAYA
MAITHON
MAITHON
BANKA
BARIPADA
BIHARSARIFF
BIHARSARIFF
BIHARSARIFF
BIHARSARIFF
PURNEA
PURNEA
GAYA
BALIA
GAYA
GAYA
JHARSUGUDA
ANGUL
JHARSUGUDA
ANGUL
DHARAMJAYGARH
DHARAMJAYGARH
SWITCHABLE
SWITCHABLE
NOW AT 220 KV
IN NER
IN NER
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
IN NR
IN NR
IN NR
IN NR
IN WR
IN WR
IN SR (SWITCH)
IN SR (SWITCH)
765 kV LINE SWITCHABLE
IN NR
766 kV LINE SWITCHABLE
IN WR (SWITCHABLE)
767 kV LINE SWITCHABLE
IN WR (SWITCHABLE)
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
IN WR (SWITCHABLE)
IN WR (SWITCHABLE)
9549
65 | P a g e
ERLDC: POSOCO
Sl No
LINE/SUB-STN
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
765 KV ANGUL
765 kV GAYA
765 KV JHARSUGUDA
765 kV PUSAULI
765 kV RANCHI NEW
ANGUL
ARAMBAGH
BAKRESWAR
BANKA
BARH
BEHRAMARA
BEHRAMPORE
BIDHANNAGAR
BIHARSHARIFF
BINAGURI
BOLANGIR
CHAIBASA
DUBURI
DURGAPUR
FARAKKA
GAYA
INDRAVATI
JAMSHEDPUR
JEERAT
JEYPORE
JHARSUGUDA
JITPL
KAHALGAON
KEONJHAR
KHARAGPUR
KISHANGANJ
KODERMA
LAKHISARAI
MAITHON
MAITHON RIGHT BANK
MUZAFFARPUR
NEW MELLI
PANDIABALLI
PATNA
PURNEA
PUSAULI
RAGHUNATHPUR
RANCHI
RANCHI NEW
RANGPO
RENGALI
ROURKELA
REACTORS CAPACITY
IN MVAR
LENGTH
( KM )
REMARKS
BUS
TOTAL
# three single phase units, whose combined capacity is indicated
2 x 330 #
2 x 240 #
2 X 240 #
1 x 330 #
2X240 #
3X125
1X50
1X50
1X80
1X80
2X63
1X80
1X50
1X50+1X80+1X125
2X125
1X80
1X80
1X80
1X50
2X50
2 X125
1X125
2X50
1X50
31.5* + 1X125 +1 x 63
2X125
2X50
2X50
1X80
1 X80
1 X 125
2X50
1 X 80
1X50
2 X 50
2X125
1X63
1X80+1X63
1X80+2x125
2X125
2 X 125
2X50
1X80+1x125
2x125
2 X 80
31.5*
1X50+1X125
765 kV
765 kV
765 kV
765 kV
765 kV
BANGLADESH
* T ertiary winding of 400/220/33 kV ICT
125
* T ertiary winding of 400/220/33 kV ICT
7983
* 31.5 MVAR reactor is connected to 33 kV tertiary winding
66 | P a g e
ERLDC: POSOCO
Annexure: VIII
Format for message to be issued by ERLDC for Real Time Outage
clearance
पावर िस टम ऑपरे शन िनगम िलिमटे ड
पव
ू ीर् क्षेत्रीय भार प्रेषण कद्र
कोलकाता - 700033
APP NO
PHONE:
FAX:
संदेश संख्या: ERLDC/Ft-02/
DATE:
T.O.O :
प्रेषक : पाली प्रभारी प्रबंधक , पव
ू ीर् क्षेत्रीय भार प्रेषण कद्र , कोलकाता
सेवा मे :
SCE/CPCC/ER-II/KOLKATA
प्रित:
1
2
3
4
SCE/SLDC/SIKKIM/GANGTOK
SCE/JLHEP
SUB: SHUTDOWN CLEARANCE
REF YOUR MSG NO. :
MAIL
DATE:
T.O.O :
The following shutdown may be availed
ELEMENT NAME
FROM
DATE
HOURS
TO
DATE
TYPE
NATURE
HOURS
PURPOSE:
CONDITIONS :
NOTE:
पाली प्रभारी प्रबंधक
1. Before aviling the shutdown, final switching off clearance must be taken from ERLDC.
2. Before requesting for the switching off/in code from ERLDC, it must be ensured that PTW has been
taken/return ,all men and materials were removed from site and all necessary safety precautions were
taken.
3. The S/D is to be returned within scheduled period.
4. ERLDC may defer/postpone the shutdown if the system condition does not permit opening of the element/s.
67 | P a g e
ERLDC: POSOCO
Annexure: IX New transmission element charging and issue of certificate of
successful trial run operation
68 | P a g e
ERLDC: POSOCO
69 | P a g e
ERLDC: POSOCO
70 | P a g e
ERLDC: POSOCO
71 | P a g e
ERLDC: POSOCO
72 | P a g e
ERLDC: POSOCO
73 | P a g e
ERLDC: POSOCO
74 | P a g e
ERLDC: POSOCO
75 | P a g e
ERLDC: POSOCO
76 | P a g e
ERLDC: POSOCO
77 | P a g e
ERLDC: POSOCO
78 | P a g e
ERLDC: POSOCO
Annexure :X
Format for Weekly Reports
EASTERN REGIONAL LOAD DESPATCH CENTRE
P OW ER SYSTEM OP ERATION CORP ORATION LIM ITED
WEEKLY REPORT
(As per IEGC Clause No.5.5)
DATE:
Year: 2016-2017 / Week No:
Period:
From
To
A) FREQUENCY PROFILE:
DATE
MAXIMUM
Freq (Hz)
Time
MINIMUM
Freq (Hz)
Time
Average
Frequency
Freq. Dev Index
(% of Time)
MIN
VDI (% of Tim e)
Frequency Range (% of time)
<49.9
49.9 - 50.05
>50.05
B) VOLTAGE (kV) :
DATE
MAX
MIN
VDI (% of Tim e)
MAX
MAX
MIN
VDI (% of Tim e)
C) MAJOR GENERATORS TRIPPED / DESYNCHRONIZED / RE-SYNCHRONIZED DURING THE WEEK
S.No
Station
Agency
Unit No.
Capacity
Outage
Date
Time
Restoration
Date
Time
Reasons
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
79 | P a g e
ERLDC: POSOCO
D)
% OF TIME N-1 CRITERIA WAS VIOLATED IN THE INTER - REGIONAL CORRIDORS
SL
INTER - REGIONAL CORRIDOR
NO
Weekly
Average
1
2
E)
% OF TIME ATC WAS VIOLATED AT THE INTER - REGIONAL CORRIDORS
EXPORT ATC
SL INTER - REGIONAL CORRIDOR
NO
1
2
3
4
F)
IMPORT ATC
NR
SR
NER
WR
% OF TIME ANGULAR DIFFERENCE BETWEEN IMPORTANT BUSES WAS BEYOND PERMISSIBLE LIMITS (30 DEGREE)
SL
PAIR OF BUSES
NO
00/01
01/01
02/01
03/01 04/01 05/01
06/01
Weekly
Average
G) IMPORTANT TRANSMISSION ELEMENTS TRIPPED / RESTORED DURING THE WEEK :
OUTAGE
RESTORATION
SL
LINE/ICT
NO
Date
Time
Date
Time
1
2
3
4
5
6
7
8
REASON/REMARKS
H) FOLLOWING ELEMENTS ARE UNDER BREAKDOWN (MORE THAN 03 MONTHS):SL
NO
Transmission Element / ICT
Outage From
Date
OWNER
Reasons for Outage
1
I) GRID DISTURBANCES / INCIDENTS (if any):
NIL
Violation Category
Voltage
Frequency
Constituents
1
2
3
4
5
6
00/01
01/01
02/01
03/01 04/01 05/01
06/01
00/01
01/01
02/01
03/01
04/01
Loading
05/01
06/01
00/01
01/01
02/01 03/01 04/01 05/01
06/01
BSPHCL
JUVNL
DVC
ODISHA
WBSETCL
SIKKIM
TOTAL
Total
J) MESSAGES ISSUED BY ERLDC, REGARDING VIOLATION CATEGORY, WHEN FREQUENCY WAS BEYOND THE BAND OF 49.9-50.05 HZ:
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
K) SPECIAL MENTION:
(U.K. VERMA)
GM, ERLDC
80 | P a g e
ERLDC: POSOCO
Annexure :XI
Format for Quarterly Reports
POWER SYSTEM OPERATION CORPORATION
EASTERN REGIONAL LOAD DESPATCH CENTRE
QUARTERLY REPORT
(AS PER IEGC CLAUSE 6.5.2 a)
Quarter No. (1,2,3or 4)
Period from: Month’yy to Month’yy
Brief report on Regional Power System / Performance of the grid is given below:
1. POWER SUPPLY POSITION
a) Peak Demand Met and Unrestricted Demand (MW)
MONTH
Month-yy
Month-yy
Month-yy
STATE
BSEB
JSEB
DVC
OPTCL
WBSETCL
REGION
BSEB
JSEB
DVC
OPTCL
WBSETCL
REGION
BSEB
JSEB
DVC
OPTCL
WBSETCL
REGION
PK DMD MET
PK REQ
SHORTGE %
b) Energy Met and Requirement (MU)
MONTH
Month-yy
STATE
ENERGY
REQ
ENERGY AVAILABILITY
OWN
SCHD
UI
SOURCE DRWL
ENERGY
MET
SHORTGE
%
BSEB
JSEB
DVC
OPTCL
WBSETCL
REGION
81 | P a g e
ERLDC: POSOCO
MONTH
Month-yy
Month-yy
STATE
ENERGY
REQ
ENERGY AVAILABILITY
OWN
SCHD
UI
SOURCE DRWL
ENERGY
MET
SHORTGE
%
BSEB
JSEB
DVC
OPTCL
WBSETCL
REGION
BSEB
JSEB
DVC
OPTCL
WBSETCL
REGION
2. REPORT ON SYSTEM CONSTRAINT ON REGIONAL GRID
The details of the system constraint in Eastern Region is given in Annexure-I.
3. QUALITY OF SERVICE
a) Frequency Profile (% time)
% of time of the month frequency remained
Month
Month’yy
Month’yy
Month’yy
<49.9
49.9-50.05
>50.05
IEGC band 49.9-50.05
Following curves are enclosed:
Annexure II - Frequency duration curve for Month’yy
Annexure III - Frequency duration curve for Month’yy
Annexure IV - Frequency duration curve for Month’yy
b) Voltage Profile
All figures in KV
JEERAT
BINAGURI
BIHARSHARIFF
MONTH MAX MIN MAX MIN MAX
Month’yy
Month’yy
Month’yy
MIN
DURGAPUR
PATNA
MAX MIN MAX MIN
82 | P a g e
ERLDC: POSOCO
Month-yy
JSEB
DVC
OPTCL
WBSETCL
REGION
7. GENERATION OF CENTRAL SECTOR THERMAL POWER STATIONS AND
THEIR DECLARED CAPACITY
PLANT
Month-yy
GEN(MU)
AVG DC
(%)
Month-yy
GEN(MU)
AVG DC
(%)
Month-yy
GEN(MU)
AVG DC
(%)
FSTPP
KhSTPP-I
KhSTPP-II
TSTPP
Event-Reporting (Clause 6.9.6):
8. GRID INCIDENCES IN ER SYSTEM
83 | P a g e
ERLDC: POSOCO
Annexure :XII
(i)
(ii)
(iii)
(iv)
(v)
(vi)
(vii)
(viii)
(ix)
(x)
Format for written report for event reporting
(vide IEGC Clause 5.3.1)
Time and date of event
Location
Plant and/or Equipment directly involved
Description and cause of event
Antecedent conditions
Demand and/or Generation (in MW) interrupted and duration of
interruption
All Relevant system data including copies of records of all recording
instruments including Disturbance Recorder, Event Logger, DAS etc.
Sequence of trippings with time.
Details of Relay Flags.
Remedial measure
84 | P a g e
ERLDC: POSOCO
Annexure:XII(a) FormatforReportingSystemDisturbances
(Detailed Report by the Constituents, as finalised by Protection Coordination Committee)
OCCURRENCE REPORT
(1)
Date & Time of Occurrence :
(2)
Name of the Sub Station / Generating Station :
(3)
Details of Occurrence :
At the time of occurrence the disposition of the feeders was as below
Bus B
Bus A
BUS COUPLER BREAKER STATUS (WHETHER “ON” / “OFF”)
For one and half breaker scheme
Feeder I
Feeder II
Tie-breaker (On/Off )
Diameter 1
Diameter 2
Diameter 3
(4)
Sequence of Trippings :
Event
Time
(hh
mm ss )
85 | P a g e
ERLDC: POSOCO
(5)
Relay Indication for Faulted Line/Transformer/Bus :
(A)
Relay Indication
Name of Bay / Line
Sl.
No.
Relay Indication
Local End
Relay type / Make
And Indications
Remote End
Relay type / Make
And Indications
1.
2.
3.
4.
(6)
Location and nature of Fault :
(7)
PLCC counter readings :
Before
Local end
After
Remote end
Before
After
CH I
CH II
(8)
(9)
Analysis:-
Restoration:Sl.No.
From
To
Duration
86 | P a g e
ERLDC: POSOCO
Remedial Measures / Lesson Learnt
Enclosure:1. Schematic Diagram showing position of (ON/OFF) breakers, Isolators and Relay
Indications.
2. DR Charts.
3. Event Logger outputs.
87 | P a g e
ERLDC: POSOCO
Annexure :XIII
Categorisation of Grid Incidences/Disturbances
Annexure XIV (a)
Sl No
Date
Name of Element/Elements
Annexure XIV (b)
Sl No Date
Name of Element/Elements Voltage Level
Tripped
220kV 400kV
Categorisation of Grid Incidents
Voltage Level
220kV
400kV
Frequency(Hz)
Before
After
Rescheduling
Required ?(Y/N)
Category of Incidence
(1/2)
Remarks if any
Categorisation of Grid Disturbance
Frequency(Hz) Antecedant
Generation
Before After Generation(MW) Lost (MW)
% age
Loss of Gen
Antecedant
Load(MW)
Lost
%age
Load(MW) Load Loss
Category
(1/2/3/4/5)
Remarks
88 | P a g e
ERLDC: POSOCO
Annexure :XIV
List of Important Elements
Tie Lines (as on 30.06.2016)
SL.NO
TIE-LINE
OWNED BY
CONNECTED SYSTEMS
LENGTH
COND.
END-2
(KM)
(TYPE)
(KV)
CKTS.
POWERGRID(NR)
POWERGRID(NR)
POWERGRID(NR)
POWERGRID(WR)
POWERGRID(WR)
272
237
356
303
149
QUAD BERSIMIS
QUAD BERSIMIS
QUAD BERSIMIS
QUAD BERSIMIS
HEXA-ZEBRA
765
765
765
765
765
D/C
S/C
S/C
D/C
D/C
261
195
QUAD-MOOSE
QUAD-MOOSE
400
400
242
321
QUAD-MOOSE
TW.MOOSE
400
400
D/C
Q/C
D/C
D/C
END-1
VOLTS NO.OF
A) 765 KV LINES
1
2
3
4
5
GAYA-VARANASI
GAYA-BALIA
PUSAULI-FATEHPUR
RANCHI(NEW)-DHARAMJAYGARH
JHARSUGUDA-DHRAMJAYGARH
6
7
8
9
MUZZFARPUR-GOROKHPUR
PATNA-BALIA
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
BARH-GOROKHPUR
SASARAM -SARNATH
SASARAM-NAVINAGAR
SASARAM -ALLAHABAD
BINAGURI-BONGAIGAON
BINAGURI-BONGAIGAON
BINAGURI-TALA I & II
BINAGURI-TALA IV
BINAGURI-MALBASE
TEESTA-RANGPO
IBEUL-RAIGARH
SEL-RAIGARH
JHRASUGUDA-IBEUL
JHRASUGUDA-RAIGARH
ROURKELA-RAIGARH
ROURKELA-SEL
RANCHI -SIPAT
BEHRAMPUR-BEHRAMARA
FARAKKA-BEHRAMPUR
FARAKKA-SAGARDIGHI
FARAKKA - MALDA
FARAKKA - PARULIA
32
33
34
35
36
37
38
39
40
41
42
43
44
45
KAHALGAON -BANKA
MAITHON - KAHALGAON
SAGARDIGHI-BEHRAMPUR
SAGARDIGHI-SUBHASGRAM
SAGARDIGHI-PARULIA
BEHRAMPUR-JEERAT
JEERAT-SUBHASGRAM
SUBHASGRAM(PG)-HALDIA
PARULIA-BIDHANAGAR
KHARAGPUR-BARIPADA
JAMSHEDPUR-MEJIA-B
MAITHON - MEJIA B
MAITHON - MEJIA B
DSTPS - JAMSHEDPUR
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
KODERMA-BIHARSARIFF
GAYA-KODERMA
MAITHON-MAITHON RIGHT BANK
RANCHI-MAITHON RIGHT BANK
RANCHI-RAGUNATHPUR
RAGUNATHPUR-MAITHON
JAMSEDPUR-AHUNIK
JAMSHEDPUR-TISCO
BARIPADA-TISCO
JEYPORE-GAZUWAKA
ANGUL-MERAMANDALI-I
ANGUL-MERAMANDALI-II
SEL- MEERAMANDALI
INDRAVATI-INDRAVATI
TSTPP-MERAMUNDALI
GMR-MERAMUNDALI
MEERAMUNDALI- NEW DUBURI
BARIPADA-MENDASAL
BARIPADA-NEW DUBURI
MENDHASAL-NEW DUBURI
JITPL-ANGUL
TSTPP - RENGALI
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID(ER)
POWERGRID(ER)
POWERGRID(ER)
POWERGRID(ER)
POWERGRID(ER)
B) 400 KV LINES
BIHARSHARIFF-BALIA
BIHARSHARIFF-VARANASI
POWERLINKS
POWERGRID
POWERGRID
POWERGRID
POWERGRID(ER)
POWERGRID(ER)
POWERGRID(NR)
POWERGRID(NR)
POWERGRID(ER) POWERGRID(NR)
POWERGRID(ER) POWERGRID(NR)
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID & IBEUL
POWERGRID & SEL
POWERGRID & IBEUL
POWERGRID
POWERGRID
POWERGRID & SEL
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID(ER)
POWERGRID(ER)
POWERGRID
POWERGRID(ER)
POWERGRID(ER)
POWERGRID(ER)
POWERGRID
POWERGRID
POWERGRID
NHPC
IBEUL
SEL
POWERGRID
POWERGRID(ER)
POWERGRID(ER)
POWERGRID
POWERGRID(ER)
POWERGRID
NTPC
NTPC
NTPC
POWERGRID(NR)
POWERGRID(NR)
NTPC
POWERGRID(NR)
POWERGRID(NER)
POWERGRID(NER)
THEP
THEP
THEP
POWERGRID
POWERGRID
POWERGRID(WR)
IBEUL
POWERGRID(WR)
POWERGRID(WR)
SEL
POWERGRID(WR)
BANGLADESH
POWERGRID
WBPDCL
POWERGRID
353
76
81
271
217
220
115*
98*
121*
11
91
147
64
110
212
113
405
71*
73
67
40
QUAD-MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
QUAD-MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
HTLS
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
POWERGRID
NTPC
POWERGRID
150
TW. MOOSE
400
D/C
S/C
D/C
S/C
D/C
D/C
D/C
S/C
S/C
D/C
S/C
S/C
S/C
S/C
S/C
S/C
D/C
D/C
S/C
S/C
D/C
S/C
POWERGRID
POWERGRID
POWERGRID
POWERGRID
WBSETCL
POWERGRID
POWERGRID
HEL
WBSETCL
WBSETCL & OPTCL
POWERGRID
POWERGRID
POWERGRID
POWERGRID
NTPC
POWERGRID
WBPDCL
WBPDCL
WBPDCL
POWERGRID
WBSETCL
POWERGRID
POWERGRID
WBSETCL
POWERGRID
POWERGRID
POWERGRID
NTPC
POWERGRID
POWERGRID
POWERGRID(ER)
WBSETCL
POWERGRID
HEL
WBSETCL
POWERGRID(ER)
DVC
DVC
48
172
26
246
171
200
80
90
11
98
168
84
TW. MOOSE
TW. MOOSE
(HTLS)
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW. MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
400
400
400
400
400
400
400
400
400
400
400
400
D/C
D/C
D/C
S/C
D/C
S/C
S/C
D/C
D/C
S/C
S/C
D/C
POWERGRID
DVC
DVC
POWERGRID
97
156
TW. MOOSE
TW. MOOSE
400
400
S/C
D/C
DVC
POWERGRID
POWERGRID
POWERGRID
POWERGRID
DVC
POWERGRID
DVC
POWERGRID
POWERGRID(ER)
POWERGRID
POWERGRID
SEL
POWERGRID(ER)
NTPC
GMR
OPTCL
POWERGRID(ER)
POWERGRID(ER)
POWERGRID(ER)
JINDAL
NTPC
POWERGRID
DVC
MPL
MPL
DVC
POWERGRID
APNRL
POWERGRID
DVC
POWERGRID(SR)
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
POWERGRID
OPTCL
OPTCL
OPTCL
POWERGRID
POWERGRID
111
82
31
188
169.17
52.9
0.3
39
116
220
25
18
220
3
51
8
90
273
190
115
85
24
QUAD-MOOSE
QUAD-MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
QUAD-MOOSE
TW. MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW.MOOSE
TW. MOOSE
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
D/C
D/C
D/C
D/C
S/C
S/C
D/C
S/C
S/C
D/C
S/C
S/C
D/C
S/C
S/C
S/C
D/C
S/C
S/C
S/C
D/C
D/C
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
APNRL
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERLINKS
OPTCL
POWERGRID
GMR
POWERGRID
OPTCL
POWERGRID
OPTCL
JINDAL
POWERGRID
89 | P a g e
ERLDC: POSOCO
Annexure XIV … contd
Tie lines cont…
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
PATNA-SIPARA
DEHRI--PUSUALI
PUSUALI-SAHUPURI
ARRAH-KHAGAUL
PATNA-KHAGUAL
SASARAM- NEW SASARAM
NEW SASARAM- ARRAH
BODHGAYA-GAYA(PG)
DEHRI-GAYA(PG)
MUZZFARPUR-KANTI
MUZZAFFARPUR-HAZIPUR-I & II
N.PURNEA - MADHEPURA
N.PURNEA - PURNEA
BALIMELA-U.SILLERU
JINDAL-JAMSHEDPUR
JODA-RAMCHANDRAPUR
BUDHIPADAR-KORBA II & III
BUDHIPADAR-RAIGARH I
TSTPP-MERAMUNDALI
TSTPP-RENGALI HPS
BISRA(PG)-TARKERA(OPTCL)
JEYPORE(PG)-JAYNAGAR(OPTCL)
TSTPP-TALCHER
FARAKKA-LALMATIA
RENGALI-RENGALI
BARIPADA-BALASORE
MAITHON(PG)-K'SWARI(DVC)
MAITHON- DUMKA
CHANDIL-SANTALDIH
RANCHI-HATIA
CHANDIL-RANCHI
TENUGHAT-BIHARSHARIF
JAMSHEDPUR-RAMCHANDRAPUR
MAITHON(PG)-DHANBAD(DVC)
PARULIA(PG)-PARULIA(DVC)
WARIA-BIDHANNAGAR
DHALKHOLA(PG)-DHALKHOLA(WB)
EM-SUBHASGRAM I &II
SUBH'GRM(PG) - NEWTOWN
SUBH'GRM(PG) - SUBH'GRM (WB)
SUBH'GRM(PG) - EMSS(CESC)
SUBH'GRM(PG) - BANTALA
BINAGURI-NJP
NJP- KISHANGANJ
BIRPARA- CHUKHA
BIRPARA-MALBASE
BIRPARA-SALAKATI
RANGPO- JLHEP
NEW MELLI- JLHEP
BSPHCL
BSPHCL
BSPHCL & UPPCL
POWERGRID
BSPHCL
POWERGRID
POWERGRID
BSPHCL & PG
BSPHCL & PG
POWERLINKS
BSPTCL
POWERGRID
POWERGRID
OPTCL & APTRANSCO
OPTCL & DVC
OPTCL & JUSNL
OPTCL & CSEB
POWERGRID
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
ECL
OPTCL
OPTCL
DVC
POWERGRID
WBSETCL & JUSNL
JUSNL
JUSNL
BSPHCL & JUSNL
POWERGRID
DVC
DVC
DVC & WBSETCL
POWERGRID
CESC
WBSETCL
WBSETCL
CESC
WBSETCL
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
DANS
DANS
POWEGRID
BSPHCL
POWERGRID
POWERGRID
POWERGRID
POWERGRID
BSPHCL
BSPHCL
BSPHCL
POWERGRID
POWERGRID
POWERGRID
POWERGRID
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
NTPC
NTPC
POWERGRID
POWERGRID
NTPC
NTPC
POWERGRID
POWERGRID
POWERGRID
POWERGRID
JUSNL
POWERGRID
JUSNL
JUSNL
POWERGRID
POWERGRID
POWERGRID
DVC
POWERGRID
CESC
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
WBSETCL
POWERGRID
POWERGRID
POWERGRID(ER)
POWERGRID
POWERGRID
117
118
119
120
121
122
123
124
125
126
127
128
129
130
131
132
133
134
135
136
137
138
139
MUZZAFARPUR- DHALKEBAR
BARHI - B'SHARIFF
BARHI-RAJGIR
DEOGHAR-SULTANGANJ
KAHALGAON-KAHALGAON
ARRAH-ARRAH
DUMRAON-ARRAH
PURNEA(PG)-PURNEA(BS)
PURNEA(PG)-KISANGANJ
DEHRI--PUSUALI
KARMANASA--PUSUALI
KARMANASA-SAHUPURI
KARMANASA-CHANDAULI
SONENAGAR - RIHAND
MAITHON-JAMTARA
KHARAGPUR-KHARAGPUR
KOLAGHAT-KOLAGHAT
MACHKUND-VIZAG
JODA-KENDPOSI
BARIPADA-RAIRANGPUR
BARIPADA-BARIPADA
GARWA-SONENAGAR
LALMATIA-SABOUR
POWERGRID
BSPHCL & DVC
BSPHCL & DVC
BSPTCL & JUSNL
POWERGRID
POWERGRID
POWERGRID
BSPHCL
BSPHCL
POWERGRID
POWERGRID
BSPHCL & UPPCL
BSPHCL & UPPCL
BSPHCL & UPPCL
DVC & JUSNL
DVC
DVC
OPTCL & APTRANSCO
OPTCL & JUSNL
OPTCL
OPTCL
BSPHCL & JUSNL
BSPHCL & JUSNL
POWERGRID
DVC
DVC
JUSNL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
DVC
DVC
DVC
OPTCL
OPTCL
POWERGRID
POWERGRID
JUSNL
JUSNL
140
141
142
143
144
145
146
147
148
149
150
151
152
153
154
155
156
157
CHANDIL-MANIQUE
PATRATU-PATRATU
GARWA-RIHAND
RANGIT-RAMMAM
KAHALGAON-SABOUR
KAHALGAON-LALMATIA
BIRPARA-BIRPARA
MALDA-MALDA
NJP-NBU
RANGIT - MELLI
ARHA-JAGDISHPUR
RANGIT-RANGPO
RANGIT-KURSEONG
RANGIT-SAGBARI
CHUJACHEN-MELLI
BANKA-SABOUR
BANKA-BANKA
JUSNL & DVC
JUSNL & DVC
JUSNL & UPPCL
POWERGRID
POWERGRID
POWERGRID
WBSETCL
WBSETCL
WBSETCL
SIKKIM
BSPHCL
POWERGRID
POWERGRID
SIKKIM
POWERGRID & GATI
BSPTCL
BSPTCL
JUSNL
JUSNL
JUSNL
NHPC
NTPC
NTPC
POWERGRID
POWERGRID
POWERGRID
NHPC
POWERGRID
NHPC
NHPC
NHPC
CHUJACHEN
POWERGRID
POWERGRID
POWERGRID
158
159
NJP-MELLI
BSPHCL
POWERGRID
UPPCL
BSPHCL
BSPHCL
BSPHCL
POWERGRID
POWERGRID
POWERGRID
BSPHCL
BSPTCL
BSPTCL
BSPTCL
APTRASCO
DVC
JUSNL
CHATTISGARH
CHATTISGARH
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
NTPC
OPTCL
OPTCL
DVC
JUSNL
WBSETCL
JUSNL
POWERGRID
BSPHCL
JUSNL
DVC
DVC
WBSETCL
WBSETCL
POWERGRID
WBSETCL
WBSETCL
CESC
WBSETCL
WBSETCL
POWERGRID
POWERGRID
POWERGRID
POWERGRID(NER)
DANS
DANS
0.5
64
72
50
25
0.2
112
96
16
22
56
100
2
24
130
127
180
81
40
40
15
6
30
79
1
77
7
73
105
34
42
182
0.5
28
1
17
3
24
26
0.5
23.2
19
0.2
108
38
40
160
10
21
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
MOOSE
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
TW.MOOSE
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA & CABLE
ZEBRA
ZEBRA
MOOSE
MOOSE
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
D/C
S/C
S/C
D/C
S/C
S/C
S/C
D/C
D/C
D/C
D/C
D/C
D/C
S/C
S/C
S/C
D/C
S/C
D/C
S/C
D/C
D/C
S/C
S/C
D/C
D/C
D/C
D/C
S/C
D/C
S/C
S/C
D/C
D/C
D/C
D/C
S/C
D/C
S/C
D/C
D/C
S/C
S/C
D/C
D/C
S/C
D/C
S/C
S/C
NEPAL
BSPHCL
BSPHCL
BSPHCL
NTPC
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
UPPCL
UPPCL
UPPCL
JUSNL
WBSETCL
WBSETCL
APTRANSCO
JUSNL
OPTCL
OPTCL
BSPHCL
BSPHCL
129
170
125
93
2
3
61
1
70
63
29
27
25
139
100
1
1
160
48
70
11
104
72
ZEBRA
LARK
LARK
PANTHER
PANTHER
PANTHER
PANTHER
LARK
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
LARK
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
S/C
S/C
S/C
S/C
S/C
S/C
S/C
T/C
S/C
S/C
S/C
S/C
S/C
S/C
S/C
S/C
S/C
S/C
S/C
S/C
S/C
S/C
S/C
DVC
DVC
UPPCL
WBSETCL
BSPHCL
JUSNL
WBSETCL
WBSETCL
WBSETCL
SIKKIM
BSPHCL
POWERGRID
WBSETCL
SIKKIM
SIKKIM
BSPTCL
BSPTCL
1
3
30
27
37
34
1
6
8
32.5
30
54
61
25
66.3
45
11
PANTHER
LARK
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER
PANTHER+ ZEBRA
PANTHER
PANTHER
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
132
D/C
S/C
S/C
S/C
S/C
S/C
D/C
D/C
D/C
D/C
S/C
S/C
S/C
S/C
S/C
S/C
S/C
C) 132 KV LINES
RANGPO-CHUJACHEN
161
RANGPO- MELLI
NJP-MELLI
LAKHISARAI - JAMAUI
162
163
RANGIT - RABANGLA
KALINGPONG-MELLI
160
132
S/C
POWERGRID
POWERGRID
SIKKIM
90
PANTHER
132
POWERGRID
POWERGRID
BSPHCL
GATI INFRA
POWERGRID
POWERGRID
POWERGRID
CHUJACHEN
SIKKIM
BSPHCL
GATI INFRA
17
90
25
20
PANTHER
PANTHER
PANTHER
ZEBRA
132
132
132
S/C
S/C
D/C
POWERGRID
WBSETCL & SIKKIM
NHPC
WBSETCL
SIKKIM
SIKKIM
25
15
LARK
DOG
66
66
S/C
D/C
S/C
90 | P a g e
ERLDC: POSOCO
Other Important Lines
S.NO
LINE
OWNED BY
CONNECTED SYSTEMS
LENGTH
COND.
VOLTS
NO.OF
END-2
(KM)
(TYPE)
(KV)
CKTS.
POWERGRID
272
Qd. BERSIMIS
765
D/C
184
89
145
231
277
217
94
196
168
71
98
240
130
195
95
95
99
167
99
100
156
72
356
171
143
82
120
130
162
130
210
185
75
80
98
177
153
200
72.5
141
77
143
110
TW. MOOSE
TW. MOOSE
TW. MOOSE
QD. MOOSE
Qd. BERSIMIS
QUAD-MOOSE
QUAD-MOOSE
QUAD-MOOSE
QUAD-MOOSE
QUAD-MOOSE
QUAD-MOOSE
QUAD-MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
TW. MOOSE
QUAD-MOOSE
TW. MOOSE
TW.MOOSE
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
400
D/C
D/C
D/C
D/C
D/C
D/C
Q/C
D/C
D/C
D/C
D/C
D/C
D/C
D/C
D/C
D/C
D/C
D/C
S/C
S/C
S/C
S/C
S/C
D/C
D/C
D/C
D/C
S/C
S/C
S/C
D/C
D/C
S/C
S/C
S/C
S/C
S/C
D/C
D/C
S/C
Q/C
D/C
D/C
40
85
75
152
68
101
112
92
21
34
63
63
44
150
1
20
41
42
55
18
70
31
16
16
55
53
51
30
6
10
90
95
61
25
120
30
101
102
34
136
6
93
20
134
135
65
68.7
176
64
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
SINGLE CORE XLPE
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
TW. MOOSE
ZEBRA
ZEBRA
ZEBRA
ZEBRA
TW. MOOSE
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
ZEBRA
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
220
D/C
D/C
D/C
D/C
D/C
S/C
S/C
S/C
D/C
D/C
S/C
S/C
D/C
D/C
S/C
D/C
S/C
D/C
T/C
S/C
S/C
D/C
D/C
D/C
D/C
S/C
D/C
S/C
D/C
D/C
D/C
D/C
D/C
Q/C
D/C
S/C
S/C
S/C
S/C
S/C
D/C
T/C
S/C
D/C
S/C
S/C
S/C
D/C
D/C
END-1
A) 765 KV LINES
1
ANGUL-JHARSUGUDA
POWERGRID
POWERGRID
B) 400 KV LINES
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
BANKA-BIHARSARIFF
LAKHISARAI-BIHARSARIFF
KAHALGAON -LAKHISARAI
BIHARSHARIFF-PURNEA
MAITHON-GAYA
KAHALGAON -BARH
BARH -PATNA
PATNA- KISHANGANJ
PURNEA - BINAGURI I & II
PURNEA-KISHANGANJ
BINAGURI-KISHANGANJ
PURNEA - MUZAFFARPUR
BIHARSHARIFF-MUZAFFARPUR
BIHARSHARIFF- PUSAULI
FARAKKA - KAHALGAON I & II
FARAKKA-KAHALGAON III & IV
BOKARO-KODERMA
MALDA - PURNEA
MERAMUNDALI - MENDASAL
RENGALI-KEONJHAR
KEONJHAR- BARIPADA
JEYPORE - INDRAVATI
INDRAVATI - RENGALI
TSTPP - ROURKELA
ROURKELA- JHARSIGUDA
JAMSHEDPUR - CHAIBASA
CHAIBASA- ROURKELA
KTPS - JEERAT
BAKRESWAR - JEERAT
BAKRESWAR - ARAMBAGH
PPSP - ARAMBAGH
PPSP - BIDHANAGAR
KTPS - ARAMBAGH
KTPS-KHARGPUR
KTPS-KHARGPUR
PARULIA - JAMSHEDPUR
MAITHON - JAMSHEDPUR
MAITHON - RANCHI
DSTPS-RAGHUNATHPUR I & II
JAMSHEDPUR-BARIPADA
RANCHI-RANCHI NEW
RANCHI-ROURKELA-I&II
BINAGURI-RANGPO
POWERGRID
POWERGRID
POWERGRID
ENICL
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERLINKS
POWERGRID
POWERGRID
POWERGRID
POWERGRID
DVC
POWERGRID
OPTCL
OPTCL
OPTCL
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
WBSETCL
WBSETCL
WBSETCL
WBSEDCL
WBSEDCL
WBSETCL
WBSETCL
WBSETCL
POWERGRID
POWERGRID
POWERGRID
DVC
POWERGRID
POWERGRID
POWERGRID
POWERGRID
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
BIHARSHARIFF-FATUAH
BIHARSHARIFF-BODHAGYA
BIHARSHARIFF-BEGUSARAI
MTPS-BEGUSARAI
MTPS-DARBHANGA
MTPS-GOPALGANJ
SASARAM-ARRAH
FATUAH-MTPS
WARIA-PARULIA
WARIA-MEJIA
CTPS A-DHANBAD
CTPS B-DHANBAD
DHANBAD-GIRIDIH
BOKARO-JAMSHEDPUR
KASBA-EMBYPASS
KASBA-SUBHASGRAM(WB)
BOKARO-CTPS
BOKARO-CTPS B
KALYANESHWARI-MEJIA
KALYANESHWARI-BURNPUR
BURNPUR-MEJIA
MEJIA-MUCHIPARA
MEJIA-BARJORA
PARULIA-MUCHIPARA
BOKARO-RAMGARH
PTPS -TENUGHAT
PATRATU-HATIA
CHANDIL-RAMCHANDRAPUR
JEYANAGAR-U.KOLAB
MERAMANDALI-NALCO
MERAMUNDALI - BIDANASI
MERAMUNDALI - DUBURI(OLD)
KATAPALLI-BUDHIPADAR
IBTPS - BUDHIPADAR
TARKERA-BUDHIPADAR
TARKERA-CHANDIPOSH
TARKERA-BARKOT
RENGALI-CHANDIPOSH
RENGALI-BARKOT
U. KOLAB-THERUVALI
U. KOLAB-JAYANAGAR
BALIMELA-JEYNAGAR
TALCHER-MERAMUNDALI
MERAMUNDALI - BHANJNAGAR
MENDHASAL -BHANJNAGAR
MENDHASAL - NAYAGARH
NAYAGARH - BHANJNAGAR
THERUVALLI - BHANJNAGAR
THERUVALLI - LAXMIPUR
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
POWERGRID
BSPHCL
DVC
DVC
DVC
DVC
DVC
DVC
CESC
WBSETCL
DVC
DVC
DVC
DVC
DVC
DVC
DVC
DVC
DVC
JUSNL
JUSNL
JUSNL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
POWERGRID
POWERGRID
NTPC
POWERGRID
POWERGRID
NTPC
NTPC
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
NTPC
NTPC
DVC
POWERGRID
OPTCL
POWERGRID
POWERGRID
POWERGRID
POWERGRID
NTPC
POWERGRID
POWERGRID
POWERGRID
WBPDCL
WBPDCL
WBPDCL
WBPDCL
WBPDCL
WBPDCL
WBPDCL
WBPDCL
POWERGRID
POWERGRID
POWERGRID
DVC
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
NTPC
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
NTPC
NTPC
DVC
POWERGRID
OPTCL
OPTCL
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
WBSETCL
WBSETCL
WBSETCL
WBSETCL
WBSETCL
WBSETCL
WBSETCL
WBSETCL
POWERGRID
POWERGRID
POWERGRID
DVC
POWERGRID
POWERGRID
POWERGRID
POWERGRID
C) 220 KV LINES
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
POWERGRID
BSPHCL
DVC
DVC
DVC
DVC
DVC
DVC
WBSETCL
WBSETCL
DVC
DVC
DVC
DVC
DVC
DVC
DVC
DVC
DVC
JUSNL
JUSNL
JUSNL
OPTCL
NTPC
OPTCL
OPTCL
OPTCL
OPGC
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OHPC
OHPC
OHPC
NTPC
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
BSPHCL
POWERGRID
BSPHCL
DVC
DVC
DVC
DVC
DVC
DVC
CESC
WBSETCL
DVC
DVC
DVC
DVC
DVC
DVC
DVC
DVC
DVC
TVNL
JUSNL
JUSNL
OHPC
NALCO
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
OPTCL
91 | P a g e
ERLDC: POSOCO
Annexure XIV …. contd
List of important Transformers
LOCATION
VOLTAGE RATIO
CAPACITY (MVA)
OWNERSHIP
A) 765/400 KV ICTS
GAYA
RANCHI NEW
SASARAM
ANGUL
JHARSUGUDA
765/400
765/400
765/400
765/400
765/400
3X1500
2X1500
2X1500
4X1500
2X1500
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
B) 400/220 KV & 400/132 KV ICTS
JAMSHEDPUR
FARAKKA
PARULIA
MALDA
BIHARSHARIF
JEYPORE
RENGALI
MAITHON
ROURKELA
RANGPO
CHAIBASA
NEW DUBURI
RANCHI
TSTPP
BINAGURI
BARIPADA
INDRAVATI HPS
KEONJHAR
BOLANGIR
ARAMBAGH
BIDHANNAGAR
KOLAGHAT TPS
BAKRESWAR TPS
SAGARDIGHI TPS
PATNA
MERAMUNDALI
MENDHASAL
KODERMA TPS
JEERAT
KHARAGPUR
BOKARO-A TPS
KISHANGANJ
TISCO
BANKA
LAKHISARAI
BARH-II STPS
KAHALGAON
GAYA
SASARAM
NEW PURNEA
MUZAFFARPUR
SUBHASGRAM
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/220
400/132
400/132
400/132
400/132
400/132
400/220
400/220
400/220
400/220
400/220
2X315
1X315
2X315
2X315
3X315
2X315
2X315
2X315
2X315
5X315
2X315
2X 315
2X315
2X315
2X315
2X315
2X315
2X315
2X315
4X315
2X315
2X315
2X315
1X315
2X315
2X315
2X315
2X315
4X315
2X315
2X315
1X 500
2X315
2X200
2 x 200
2X200
2X200
1X315 + 1X500
1 X 500 + 1X315
1 X 500 + 1X315
2X315 + 1 X 500
4X315+1X500
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID
NTPC
POWERGRID
POWERGRID
POWERGRID(1) + OHPC(1)
POWERGRID
POWERGRID
WBSETCL
WBSETCL
WBPDCL
WBPDCL
WBPDCL
POWERGRID
OPTCL
OPTCL
DVC
WBSETCL
WBSETCL
DVC
POWERGRID
DVC
POWERGRID
POWERGRID
NTPC
NTPC
POWERGRID
POWERGRID
POWERGRID
POWERGRID
POWERGRID(2+1) + CESC(2)
92 | P a g e
ERLDC: POSOCO
Annexure XIV (contd)
List of Reactors and Harmonic Filters
LENGTH
Sl No
LINE/SUB-STN
REACTORS CAPACITY
IN MVAR
( KM )
LINE
1
2
BEHRAMPUR-JEERAT
SAGARDIGHI-SUBASHGRAM
200
256.3
3
4
5
6
7
8
9
11
12
14
15
16
FARAKKA-PARULIA-I
BIDHANAGAR-PARULIA I
LAKHISARAI-B'SHARIFF-I
LAKHISARAI-B'SHARIFF-II
K'GAON-MAITHON-I
K'GAON-MAITHON-II
ROURKELLA-CHAIBASA-I
ROURKELA-TALCHER I
ROURKELA-TALCHER II
ROURKELA- JAMSHEDPUR-II
KEONJHAR-BARIPADA
BARIPADA-MENDASAL-II
150
11
89
89
172
172
120
175
175
17
18
19
BAKRESWAR-ARAMBAGH
BAKRESWAR-JEERAT
RENGALI-INDRAVATI
132
162
356
20
21
22
23
24
25
26
27
28
29
32
B'SHARIFF-TENUGHAT
MALDA-PURNEA -I
MALDA-PURNEA -II
BINAGURI-BONGAIGAON-I
BINAGURI-BONGAIGAON-II
BINAGURI-BONGAIGAON-III
BINAGURI-BONGAIGAON-IV
BINAGURI-TALA-I
BINAGURI-TALA-II
BINAGURI-TALA-IV
PURNEA-MUZAFFARPUR-I
180
167
167
216
216
224
224
115
115
98
240
33
PURNEA-MUZAFFARPUR-II
240
34
35
36
37
38
ROURKELA-JHARSUGUDA- I
ROURKELA-STERLITE-I
MERAMUNDALI-ANGUL-I
ANGUL-BOLANGIR
BOLANGIR-JEYPORE
142
113
20.8
199
288
39
40
41
42
43
44
45
46
47
48
B'SHARIFF-PUSAULI -I
PUSAULI-ALLAHABAD
PUSAULI-SARNATH
MUZAFFARPUR-GRKPR-I
MUZAFFARPUR-GRKPR-II
B'SHARIFF-BALIA -I
B'SHARIFF-BALIA -II
PATNA-BALIA-III
PATNA-BALIA-IV
RANCHI-SIPAT-I
195
271
260
260
242
242
185
185
405
49
RANCHI-SIPAT-II
405
50
51
52
JEYPORE-GAJUWAKA-I
JEYPORE-GAJUWAKA-II
MPL-RANCHI -I
220
220
188
156
273
53
MPL-RANCHI -II
188
54
55
56
PUSAULI-BIHARSHARIFF-I
PUSAULI-BIHARSHARIFF-II
765 kV PUSAULI-FATHEPUR
198
198
356
57
765 kV RANCHI-DHRAMJAYGARH I
303
58
765 kV RANCHI-DHRAMJAYGARH II
303
59
60
61
LAKHISARAI-KhSTPP - I
LAKHISARAI-KhSTPP - II
PATNA - KISHANGUNJ-I
145
145
352
62
PATNA - KISHANGUNJ-II
352
63
MAITHON-GAYA-I
235
64
MAITHON-GAYA-II
235
65
66
67
68
69
70
71
72
73
74
MAITHON-MEJIA-I
BANKA-BIHARSARIFF I & II
BARIPADA-KEONJHAR
BIHARSARIFF-PURNEA I
BIHARSARIFF-PURNEA II
BIHARSARIFF-VARANASI-I
BIHARSARIFF-VARANASI-II
PURNEA- BINAGURI-I
PURNEA- KISHANGANJ-I
765 KV GAYA- BALIA
83
185
156
232
232
321
321
168
71
120
75
76
77
765 KV GAYA- VARANASI-I
766 KV GAYA- VARANASI-II
765 KV JHARSUGUDA-ANGUL I
272
272
273
78
765 KV JHARSUGUDA-ANGUL II
273
79
80
764 KV JHARSUGUDA-DHARAMJAYGARH-I
765 KV JHARSUGUDA-DHARAMJAYGARH- II
151
151
TOTAL
REMARKS
END
1X50
1X63
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1X50
1 X 63
1 X 63
1X63
1X63
1x50
1x50
1x50
1x63
1x63
1X63
1X63
1X80
1X80
1X63
1X63
1X63
1x63
1x63
1x63
1x63
1x63
1X63
1x80
1x50
1x50
1x80
1X50
1X63
1X63
1X63
1X50
1X50
1X50
1X63
1X63
1X80
1X80
1X80
1X80
1X80
1X80
1 X50
1 X50
1 X50
1 X50
1 X63
1 X63
1 X 330 #
1 X 330 #
1 X 240 #
1 X 330 #
1 X 240 #
1 X 330 #
1 X 50
1 X 50
1 X 63
1 X 63
1 X 63
1 X 63
1 X 50
1 X 50
1 X 50
1 X 50
1 X 50
2 X 50
1 X 50
1 X 80
1 X 80
1 X 50
1 X 50
1 X 63
1 X 63
1 X 240 #
1 X 330 #
1 X 240 #
2 X 240 #
1 X 240 #
1 X 240 #
1 X 240 #
1 X 240 #
1 X 330 #
1 X 330 #
JEERAT
SAGARDIGHI
SUBHASGRM
FARAKKA
PARULIA
B'SHARIFF
B'SHARIFF
MAITHON
MAITHON
ROURKELA
TSTPP
TSTPP
ROURKELA
BARIPADA
MENDASAL
BARIPADA
BAKRESWAR
JEERAT
RENGALI
INDRAVATI
TENUGHAT
MALDA
MALDA
BONGAIGAON
BONGAIGAON
BINAGURI
BINAGURI
BINAGURI
BINAGURI
BINAGURI
PURNEA
MZFRPR
PURNEA
MZFRPR
ROURKELA
ROURKELA
MERAMUNDALI
BOLANGIR
BOLANGIR
JEYPORE
BIHARSARIFF
PUSAULI
PUSAULI
MUZAFFARPUR
MUZAFFARPUR
BALIA
BALIA
BALIA
BALIA
RANCHI
SIPAT
RANCHI
SIPAT
GAJUWAKA
GAJUWAKA
MPL
RANCHI
MPL
RANCHI
PUSAULI
PUSAULI
PUSAULI
FATHEPUR
RANCHI
DHARAMJAYGARH
RANCHI
DHARAMJAYGARH
LAKHISARAI
LAKHISARAI
PATNA
KISHANGANJ
PATNA
KISHANGANJ
GAYA
MAITHON
GAYA
MAITHON
MAITHON
BANKA
BARIPADA
BIHARSARIFF
BIHARSARIFF
BIHARSARIFF
BIHARSARIFF
PURNEA
PURNEA
GAYA
BALIA
GAYA
GAYA
JHARSUGUDA
ANGUL
JHARSUGUDA
ANGUL
DHARAMJAYGARH
DHARAMJAYGARH
SWITCHABLE
SWITCHABLE
NOW AT 220 KV
IN NER
IN NER
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
IN NR
IN NR
IN NR
IN NR
IN WR
IN WR
IN SR (SWITCH)
IN SR (SWITCH)
765 kV LINE SWITCHABLE
IN NR
766 kV LINE SWITCHABLE
IN WR (SWITCHABLE)
767 kV LINE SWITCHABLE
IN WR (SWITCHABLE)
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
SWITCHABLE
IN WR (SWITCHABLE)
IN WR (SWITCHABLE)
9549
93 | P a g e
ERLDC: POSOCO
Annexure XIV.. contd
Sl No
LINE/SUB-STN
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
765 KV ANGUL
765 kV GAYA
765 KV JHARSUGUDA
765 kV PUSAULI
765 kV RANCHI NEW
ANGUL
ARAMBAGH
BAKRESWAR
BANKA
BARH
BEHRAMARA
BEHRAMPORE
BIDHANNAGAR
BIHARSHARIFF
BINAGURI
BOLANGIR
CHAIBASA
DUBURI
DURGAPUR
FARAKKA
GAYA
INDRAVATI
JAMSHEDPUR
JEERAT
JEYPORE
JHARSUGUDA
JITPL
KAHALGAON
KEONJHAR
KHARAGPUR
KISHANGANJ
KODERMA
LAKHISARAI
MAITHON
MAITHON RIGHT BANK
MUZAFFARPUR
NEW MELLI
PANDIABALLI
PATNA
PURNEA
PUSAULI
RAGHUNATHPUR
RANCHI
RANCHI NEW
RANGPO
RENGALI
ROURKELA
LENGTH
( KM )
REACTORS CAPACITY
IN MVAR
REMARKS
BUS
2 x 330 #
2 x 240 #
2 X 240 #
1 x 330 #
2X240 #
3X125
1X50
1X50
1X80
1X80
2X63
1X80
1X50
1X50+1X80+1X125
2X125
1X80
1X80
1X80
1X50
2X50
2 X125
1X125
2X50
1X50
31.5* + 1X125 +1 x 63
2X125
2X50
2X50
1X80
1 X80
1 X 125
2X50
1 X 80
1X50
2 X 50
2X125
1X63
1X80+1X63
1X80+2x125
2X125
2 X 125
2X50
1X80+1x125
2x125
2 X 80
31.5*
1X50+1X125
TOTAL
# three single phase units, whose combined capacity is indicated
765 kV
765 kV
765 kV
765 kV
765 kV
BANGLADESH
* T ertiary winding of 400/220/33 kV ICT
125
* T ertiary winding of 400/220/33 kV ICT
7983
* 31.5 MVAR reactor is connected to 33 kV tertiary winding
SERIES COMPENSATION ELEMENTS & HVDC CONVERTERS
1
2
3
4
5
5
FSC + TCSC AT PURNEA END OF 400KV PURNEA - MUZAFFARPUR I & II
FSC AT JEYPORE END OF 400KV BOLANGIR-JEYPORE LINE
FSC AT JEYPORE END OF 400KV JEYPORE - GAJUWAKA I& II
FSC AT RENGALI END OF 400KV RENGALI - INDRAVATI LINE
FSC AT RANCHI END OF 400 KV RANCHI-SIPAT I & II
500MW HVDC BACK-TO-BACK CONVERTER AT SASARAM
Filters at Gazuwaka East
106 MVAR Doubled Damped Filter
106 MVAR 3rd Harmonic/Doubled Damped Filter
50 MVAR Bus Reactor
Filters at Talcher
Doubled Damped filter
120 MVAR (Switchable)
97 MVAR
66 MVAR Shunt Capacitor
72.6 MVAR Shunt Capacitor
Filters at Pusauli
112 MVAR at North Bus
112 MVAR at East Bus
Filters at Bheremara
91 MVAR at 400 kV Side
91 MVAR at 230 kV Side
Number
1
2
2
Number
6
3
1
2
Number
4
4
Number
4
4
94 | P a g e
ERLDC: POSOCO
List of Important Generators
Control Area
Station
Type
Owner
Farakka
Farakka STPS Stage I & II
Farakka STPS Stage III
Kahalgaon STPS Stage I
Kahalgaon STPS Stage II
Talcher STPS Stage I
Talcher STPS Stage II
ISGS Thermal
ISGS Thermal
ISGS Thermal
ISGS Thermal
ISGS Thermal
ISGS Thermal
ISGS Thermal
ISGS Hydro
ISGS Hydro
ISGS Hydro
ISGS Hydro
ISGS Hydro
ISGS Hydro
ISGS Hydro
Thermal
Hydro
Thermal
Thermal
Thermal
Thermal
Thermal
Thermal
Thermal
Thermal
Thermal
Thermal
Thermal
Thermal
Hydro
Hydro
Thermal
Thermal
Thermal
Thermal
Thermal
Hydro
Hydro
Hydro
Hydro
Thermal
Thermal
Thermal
Thermal
Thermal
Thermal
Hydro
Hydro
NTPC
NTPC
NTPC
NTPC
NTPC
NTPC
NTPC
NHPC
NHPC
DGPC(Bhutan)
DGPC(Bhutan)
DGPC(Bhutan)
DGPC(Bhutan)
DGPC & TATA
TVNL(JSEB)
JSEB
DVC
DVC
DVC
DVC
DVC
DVC
DVC
WBPDCL
WBPDCL
WBPDCL
WBPDCL
WBPDCL
NHPC
WBSEDCL
DPL
DPL
HEL
CESC
OPGC
OHPC
OHPC
OHPC
OHPC
MPL
APNRL
SEL
GMR-Infra'
JINDAL
IBEUL
DANS
GATI
Kahalgaon
Talcher Stg I
Talcher Stg II
Barh
Teesta -V
Rangit
Bhutan
Bhutan
Bhutan
Bhutan
Bhutan
Teesta
Rangit
Tala
Chukha
BHPC
Kurichu
Dagachu
Tenughat
Jharkhand
Subarnarekha
Waria
Mejia
CTPS B
Mejia-B
DVC
Koderma TPS
Bokaro"B"
DSTPS
Kolaghat
Sagardighi
Bakreswar
Santaldih
Bandel
TLDP
West Bengal
PPSP
DPL
DPL
HALDIA
Budge-Budge
IB
Balimela
U-Kolab
Orissa
U-Indravati
Rengali
MPL
ADHUNIK
Sterlite*
GMR*
IPP
JITPL
INDBHARAT
JLHEP
CHJACHEN
* one unit of Sterlite and GMR is dedicated to Odisha
Capacity(MW)
3x200+2x500
1x500
4x210
3x500
2x500
4x500
2X660
3x170
3x20
6x170
4x84
20X2+2X12
4x15
2x63
2x210
2X65
(U#4) 210
4X210+2X250
2 X 250
2 X 500
2 x 500
3x210
2 X 500
6x210
2x300
5x210
2 X 250
U#5 (210)
4x33
4X225
(U#7) 300
(U#8) 250
2X300
3X250
2x210
6x60+2x75
4x80
4x150
4x50
2 x 525
2X270
4X600
3x350
2x600
2X350
2X48
2 X 55
95 | P a g e
ERLDC: POSOCO
Annexure :XV
Automatic UFR load shedding Schemes and Feeder Disconnection
to control overloading
96 | P a g e
ERLDC: POSOCO
Annexure: XV (Cont…)
Feeder wise detail of Bihar UFR relay
97 | P a g e
ERLDC: POSOCO
Annexure: XV (Cont…)
Feeder wise detail of Jharkhand UFR relay
98 | P a g e
ERLDC: POSOCO
Annexure: XV (Cont…)
Feeder wise detail of DVC UFR relay
99 | P a g e
ERLDC: POSOCO
Annexure: XV (Cont…)
Feeder wise detail of Odisha UFR relay
100 | P a g e
ERLDC: POSOCO
Annexure: XV (Cont…)
Feeder wise detail of West Bengal UFR relay
101 | P a g e
ERLDC: POSOCO
Annexure: XV (Cont…)
Feeder wise detail of CESC UFR relay
Settings of Under frequency relays
CESC system
Stage
132/33kV G/S/S
CHAKMIR
49.2Hz
NCGS
DUMDUM
49.0Hz
BBGS
MAJERHAT
48.8Hz JADAVPORE
KRS
PRS
NCGS
48.6Hz
LILUAH
33kV Feeder
Stage‐I
55 MVA TRF ‐ 1 & 2
KAMARHATI TRF ‐ 1
KUTIGHAT TRF ‐ 3
TOTAL
Stage‐II
NEW DUMDUM TRF ‐ 1
NEW DUMDUM TRF ‐ 2
SOUTH DUMDUM TRF ‐ 1
DUMDUM TRF ‐ 3
BAURIA 1 & 3
FORESHORE RD D/S( 6 KV FEEDER)
SALIMAR D/S ( 6 KV FEEDER)
TOTAL
Stage‐III
DIAMOND CITY WEST D/S
THAKURPUKUR TRF ‐ 1
THAKURPUKUR TRF ‐ 2// BEHELA(N) TRF ‐ 1
SOUTHCITY D/S TRF ‐ 2
TOLLYGUNJE(N) D/S TRF ‐ 1/ SOUTH CITY TRF ‐ 1
BALLYGUNJE D/S 6 KV TRF ‐ 1
PRINCEP ST D/S (6 KV FEEDER)
KUTIGHAT TRF ‐ 1
KUTIGHAT TRF ‐ 2
KUTIGHAT TRF ‐ 4
TOTAL
Stage‐IV
132 KV LILUAH ‐ CESC(BRS) 1,2 &3 AT WBSETCL LILUAH S/S
TOTAL
Max Load in MW
SUMMER
WINTER
47
29
8
6
10
8
65
43
15
14
15
12
18
9
7
90
11
9
8
7
12
5
3
55
13
10
7
4
24
13
14
8
23
8
16
6
6
6
125
15
5
10
4
4
4
75
120
70
120
70
102 | P a g e
ERLDC: POSOCO
Annexure: XV (Cont…)
Priority wise Feeders/ICTs identified to be disconnected in case of over drawal
Bihar
Priority
1
2
3
Feeders/ICTs
400/220 kV 315 MVA ICT at Biharsariff
132 kV Arrah (PG)- Arrah (BSPHCL)
132 kV Purnea(PG)-Purnea(BSPHCL)
Point of Disconnection
400 kV Biharsariff PG
132 kV Arrah PG
132 kV Purnea PG
Feeders/ICTs
One 400/220 kV 315 MVA ICT
Jamsedpur
220 kV Ranchi(PG)-Chandil(JUVNL)
Point of Disconnection
400 kV Jamsedpur
Jharkhand
Priority
1
2
220 kV Ranchi-PG
DVC
Priority
1
2
3
Feeders/ICTs
220 kV Maithon (PG)-Kalyaneswari
(DVC)
220 kV Parulia (PG)-Parulia (DVC)
220 kV Maithon (PG)-Dhanbad (DVC)
Point of Disconnection
220 kV Maithon-PG
220 kV Parulia PG
220 kV Maithon-PG
Feeders/ICTs
220 kV Rengali(PG)-Rengali(OPTCL)
220/132 kV Baripada 160 MVA ICT
220 kV Baripada(PG)-Balsore (Odisha)
Point of Disconnection
220 kV Rengali-PG
220 kV Baripada-PG
220 kV Baripada-PG
Feeders/ICTs
220 kV Dalkohla (PG)-Dalkohla(WB)
132 kV Malda (PG)-Malda(WB)
220 kV Subhasgram(PG)Subhashgram(WB)
Point of Disconnection
220 kV Dalkohla-PG
132 kV Malda-PG
220 kV Subhasgram PG
Odisha
Priority
1
2
3
West Bengal
Priority
1
2
3
103 | P a g e
ERLDC: POSOCO
Annexure :XVI
Power Demand Override
PDOs at Talcher
Sl No
1
2
3
4
5
6
7
Number of Connected generators /AC
lines
6
5
4
3
2
1
0
DC Power Limit in MW
No Limit
No Limit
No Limit
1500 MW
1000 MW
500 MW
Controlled Shut down /ESOF
PDOs at Kolar
Sl No
1
2
3
4
5
6
7
Number of Connected generators /AC
lines
6
5
4
3
2
1
0
DC Power Limit in MW
No Limit
2000 MW
1500 MW
1000 MW
500 MW
Controlled Shut down
Controlled Shut Down/ ESOF
PDO (Run Back) at HVDC Gajuwaka
Totally 16 PDO’s can be programmed at HVDC Gajuwaka .Presently only 4 PDO’s have been used and they
are detailed below
PDO’s at HVDC Gajuwaka Poles
SL NO
Type of PDO
Contingency
DC Powerlimit
1
PDO-2
East Bus AC U/V Relay set at Vs – 87.5 V or
318 kV ( on 400 kV side on any phase- phase)
500 MW
2
PDO-4
500 MW
3
PDO-5
4
PDO-6
Tripping of
 Jeypore –Indravati 400kV S/C
 Jeypore-meramundali 400kV S/C
 One ckt of Jeypore-Gazuwaka 400kV
D/C
 Both 400/220kV Jeypore ICTs
 Jeypore-Jeynagar 220kV D/C
East Bus frequency at 49.0 Hz and below.
Rate of fall of frequency df/dt – 0.3 Hz./sec
Overload Trip contact of Gajuwaka S/s ICT
on southern side
150 MW
250MW
104 | P a g e
ERLDC: POSOCO
Annexure : XVII
Special Protection schemes at Talcher and Kolar
SPS 450
Under this mode of SPS the power injection to N-E-W grid is limited to 450 MW.
The actual generation by the generators is considered for building the logic.
Logic for single pole tripping:
This logic is based on the assumption that during the tripping of one pole of HVDC the other
available pole will automatically ramp up to 1250 MW. The logic is built using power relays
and the logic adopted is detailed below.
One pole trips
AND
Total Power injected by generators is more than 1700 MW
THEN
Tripp one of the selected unit (Presently unit six selected) instantly
Logic for Bipole tripping
Presently this logic is built using power relays and the logic adopted is
detailed below.
If Both Poles trip
AND
Power injected by Generators is more than 1100 MW
THEN
Trip two nos of selected units( presently unit six and three are selected)
IF
The total power injected by the generators is still more than 550 MW for more than 250
milliseconds
THEN
Trip Unit 4
SPS 1000
Under this mode of SPS the power injection to N-E-W grid is limited to 1000 MW. The actual
injection to the HVDC system (by measuring the flow on four a/c lines between TSTPS and
Talcher HVDC station) is considered for building the logic. Under SPS 1000 scheme no
generation shedding is required for a single pole tripping. For contingencies of both pole
tripping and for single pole tripping with the HVDC system going to ground return mode,
generation shedding will be done. Extent of generation shedding depends on the actual
power flow through the HVDC link and to limit the actual injection to N-E-W grid to 1000 MW
105 | P a g e
ERLDC: POSOCO
106 | P a g e
ERLDC: POSOCO
HVDC INTER TRIP SCHEME (SPS 1000)
Sl number
Condition
Unit 6
Trip
1
IF THE HVDC POWER FLOW IS MORE THAN 1600 MW & BOTH POLE BLOCKED
Unit 5
Unload by 150 MW
Unit 4
Unload by 150 MW
IF THE HVDC POWER FLOW IS BETWEEN 1450 MW TO 1600 MW & BOTH POLE BLOCKED
Unit 6
Trip
Unit 5
Unload by 150 MW
Unit 4
No effect
IF THE HVDC POWER FLOW IS MORE THAN 1600 MW & ONE POLE BLOCKED WITH REMAINING POLE ON GROUND RETURN MODE
Unit 6
Trip
Unit 5
Unload by 150 MW
Unit 4
No effect
IF THE HVDC POWER FLOW IS BETWEEN 1300 MW TO 1450 MW & BOTH POLE BLOCKED
Unit 6
Unit 5
Unload by 150 MW
Unload by 150 MW
Unit 4
Unload by 150 MW
Unit 6
Unload by 150 MW
Unit 5
Unload by 150 MW
Unit 4
Unload by 150 MW
Unit 6
Unit 5
Unit 4
Unload by 150 MW
No effect
Unload by 150 MW
Unit 6
Unload by 150 MW
Unit 5
No effect
Unit 4
Unload by 150 MW
Unit 6
Unload by 150 MW
8
IF THE HVDC POWER FLOW IS BETWEEN 1000 MW TO 1150 MW & BOTH POLE BLOCKED
Unit 5
Unit 4
No effect
No effect
Unit 6
Unload by 150 MW
9
IF THE HVDC POWER FLOW IS MORE BETWEEN 1000 MW TO 1150 MW & ONE POLE BLOCKED WITH REMAINING POLE ON Unit 5
No effect
Unit 4
No effect
2
3
4
5
IF THE HVDC POWER FLOW IS MORE BETWEEN 1450 MW TO 1600 MW & ONE POLE BLOCKED WITH REMAINING POLE ON GROUND RETURN MODE
6
IF THE HVDC POWER FLOW IS BETWEEN 1150 MW TO 1300 MW & BOTH POLE BLOCKED
7
IF THE HVDC POWER FLOW IS MORE BETWEEN 1300 MW TO 1450 MW & ONE POLE BLOCKED WITH REMAINING POLE ON GROUND RETURN MODE
Action
107 | P a g e
ERLDC: POSOCO
Annexure :XVIII
Islanding schemes in ER
Station/System
Islanding scheme
Criteria
CHPC (Bhutan)
One machine (84 MW) alongwith
Thimpu Load gets islande with opening
of bus coupler breaker
The entire system gets islanded at
Kasba ( the synchronising point)
Low
Frequency( 47.0Hz)
CESC
NALCO(CPP in
Orissa system)
ICCL(CPP within
Orissa system)
RSP (CPP in Orissa
system)
Bhushan Power &
Steel (CPP in Orissa
system)
Arya ISPAT and
power Ltd. (CPP in
Orissa system)
Main –I bus connects all lines
connecting OPTCL Network
Main –II bus connects plant load and
generators
Bus coupler breaker opens to isolate
plant with generators from rest of the
system
The plant gets connected to OPTCL
network at 132kV.
The 132/33 kV Transformer gets
isolated from 132kV system
CP2 has 2 units 60MW each generating
at 11kV and connected to 132 bus
through 132/33 transformer
CP1 has 3 units, 45 MW each,
generating at 6.6 kV and connected to
33
kV
bus
through
33/6/6kV
Transformer
Scheme I : All units gets islanded by
opening of 132kV lines
Scheme II: One unit may reamin with
Grid and get islanded by opening of
132kV and 33kV Bus coupler CBs
130MW TG#1 & TG#2 will get
islanding status in Governor, AVR and
Siprotect Relays through PLC Logic.
For this all status of breaker in MRSS
(220kV Main breaker# 1,220kV Main
breaker#2, and Bus coupler) and 220kV
cable feeder #1 at 130MW power plant
wired up to PLC in 130MW
Whenever the 18 MW TG set is running
in synchronization condition with OPTCL
Grid following relays have been nvisaged
for islanding purpose of 18 MW TG set:
1)MICOM-P341, Areva make
2)6RW 6000, Siemens make
MICOM-P341 shall sense any rate of
changed of frequency and the variation of
voltages between Grid supply and
Low frequency (47.8
Hz)
Or
High frequency (52.5
Hz)
Low Freq( 47.4 Hz)
Low Freq ( 47.5 Hz)
Low frequency(Both
the schemes operate at
47.6 Hz)
Under frequency 47.5
Hz for 2.5 Sec
Over Frequency 52.6 Hz
for 2.5 Sec
108 | P a g e
ERLDC: POSOCO
generation. Accordingly, it shall give trip
command to Grid incomer breaker.
Instead of above, the electrical quantities
like U/V, O/V, U/F, O/F are measured by
MICOM-P341 as well as 6RW 6000 and
give trip command to Grid incomer
breaker
Maithon Ispat
Limited (CPP in
Orissa system)
In the scheme, Micom P 341 Relay, Areva
Make, operates during Grid Disturbance
and it gives Trips command to SMS TIE
2 breaker and 220 kV incomer breaker
and consequently incomer breaker gives
trip command to 20/25 and 28/35 MVA
transformer 220 kV incomer breaker
and 11 kV ALONE Breaker through
interlocks
Whenever there is a disturbance in the
system, the relay calculates the current &
voltage parameters and evaluates the type
of fault. Then the relay gives the alarm/
trip command. When a trip command
actuates by the relay, it operates the
master trip relay and subsequently trips
the corresponding 132KV Grid incomer
breaker. This results in clearing the fault
and isolating the TG set from feeding the
fault current. Also there is a provision for
tripping of downstream 33KV Grid
Hindalco(CPP in
The power system of CGP of Hindalco
Orissa system)
Industries Ltd is connected to grid at 132
kV level through two number of Alco
feeders from Burla Power House to their
132 kV main receiving substation. They
have got grid islanding scheme in order to
survive during grid disturbance. The
disturbance in the grid is sensed by the
Numerical Relay Micom P 341 through
following four criteria and it opens the
grid connecting breakers in their main
receiving substation.
IMFA (CPP in Orissa Islanding of 108 MW captive Power Plant
system)
is done by sensing frequency
IFFCO (CPP in
Orissa system)
IBTPS
Under frequency 48.0
Hz for 0 Sec
Over Frequency 52.0 Hz
for 1.0 Sec
Under frequency 48.0
Hz
Over Frequency 51.5 Hz
Under frequency 48.0
Hz
Rate of fall of frequency
0.8Hz/Sec
Islanding of IBTPS is done using LADR
(Load Accessed Directional Relay)
technique.
From every feeder, lock out tripping pulse
is extended to LADR relay at BC panel.
Continuously the dI/dt on the system due
to the available of target loads and
enerators are monitored by the relay and
as per the
109 | P a g e
ERLDC: POSOCO
VAL (CPP in Orissa
system)
allowable load limit, this relay sends
command for shedding.
Different proposed islanding scheme:Islanding Scheme:Bus-1:- IB (1,3), AT1&2, Korba-2,
Bhusan-(1,2), SPS
Bus-2:- IB (2,4), Vedanta(1,2), Korba3,Katapali (1,2) Tarkera(1,2), Raigarh
VAL is a captive power plant having
generation of 9 x 135 MW and
connected to the grid at 220 kV level
via 220 kV VAL-Budhipadar D/C line.
It has a facility to island itself from grid
in case of any sever disturbance in
grid
Under frequency 48.5Hz
Rate of fall of frequency
1.2 Hz/Sec 0.2 Sec
delay.
Under frequency 48.0
Hz 0.5 Sec delay.
110 | P a g e
ERLDC: POSOCO
Annexure :XIX
Scheduling Formats ( Broad guidelines for the Formats)
Form A:
1.
DC Declaration by ISGS Thermal
Time Block
1
2
3
.
.
.
.
.
96
1.
2.
3.
4.
For Date:
Station 1 Ex(PP) DC MW
Station 2 Ex(PP) DC MW
Station N Ex(PP)DC MW
Technical Minimum Limit (MW) upto which station can be backed down
without restoring to oil support
Ramp up Rate MW/min or steps of load raising in avg MW
Ramp Down Rate MW/min steps of load lowering in Avg MW
Remarks : Unit under Maintenance/Overhauling/Other constarints
Form A for ISGS Hydro
C A P A C IT Y D E C L A R A T IO N (E X -B U S )
TO : S C E , E R L D C , K O L K ATA
F R O M : S H IF T IN C H A R G E … … … … … . P O W E R S T A T IO IN
D E C L A R E D C A P A C IT Y (E X - B U S ) O F … … ... P O W E R
S T A T IO N
M SG. NO.
REV . N o.
(A ) D E C L A R E D C A P A B IL IT Y
(i)
FO R D ATE
D ATE O F
IS S U E
U N IT N o s .
C a p a b ility a t 0 0 :0 0 H rs . o f n e x t d a y
T IM E
C A P A B IL IT Y E xB U S (M W )
T IM E (h h :m m )
1
0 :0 0 T O 2 4 :0 0
2
0 :0 0 T O 2 4 :0 0
0 :0 0 T O 2 4 :0 0
3
(ii)
U n its to g o u n d e r p la n n e d s h u td o w n
day
d u rin g n e xt
N IL
U n its lik e ly to re tu rn fro m p la n n e d s h u td o w n d u rin g
(iii) n e xt d a y
N IL
T IM E D U R A T IO N
(iv ) D e c la re d c a p a b ility b a s e d o n A -(i), (ii) &
(v )
(iii) a b o v e
FROM
TO
0 0 :0 0
2 4 :0 0 :0 0
D E C L A R E D C A P A B IL IT Y O F E X B U S
(M W )
SU G G ES TE D SC HED ULE
F ro m
(h h :m m )
0 0 :0 0
To
(h h :m m )
D C E x-b u s (M W )
2 4 :0 0
E x- B us M W H
N H P C D AT A F O R TH E D AT E
(v i)
D C (E ) (M W H )
( v ii)
( v iii)
( ix )
(B )
( i)
( ii)
( iii) _
( iv )
REV NO
MSG NO
A c tu a l E x- b u s (A ) (M W H )
A d ju s te d p ro p o s e d to b e m a d e in
s c h e d u le
(A -E ) (M W H )
D e c la re d C a p a c ity ( T h e m a x im u m M W a v a ila b le fo r 3 h rs . o r m o re D u rin g p e a k in g )
MW
M a xim u m a v a ila b le c a p a c ity o f E x- b u s u n d e r n o rm a l v o lta g e a n d fre q u e n c y
MW
%
C a p a c ity In d e x [(v ii) / (v iii)*1 0 0 ]
R E S E R V O IR L E V E L A N D IN F L O W S S T A T U S
R e s e rv o ir le v e l (C u rre n t)
m tr.
A v e ra g e In flo w s o n p re v io u s d a y
C um ecs
C um ecs
A n tic ip a te d a v e ra g e in flo w s fo r th e n e x t d a y
O v e rlo a d C a p a c ity
(v )
T im e d u ra tio n fo r w h ic h m a x im u m g e n e ra tio n c a n b e s u s ta in e d a t a
s tre tc h (D e p e n d in g U p o n A n tic ip a te d in flo w )
( v i)
M in im u m 'm u s t ru n ' g e n e ra tio n (if a n y ) a lo n g w ith tim e p e rio d
G e n e ra tio n
(M W )
T IM E (h h :m m )
( v ii) A n y o th e r c o n s tra in ts
R E M A R K S :-
S H IF T IN C H A R G E
111 | P a g e
ERLDC: POSOCO
Form B
Statement of Entitlement for beneficiaries
Constituent :
Time
Block
Stn 1
For Date
Ex(PP) DC Declared by ISGSs
Stn 2
.
.
Stn N
Stn 1
Ex(PP) Entitlement from
Stn 2
.
.
Stn N
1
2
3
Time Block
DC
96
Fig : in MW
Form C:
Statement of Requisitions from Beneficiaries
Time
Block
Stn 1
For Date:
Ex(PP) Requisitions from ISGSs
Stn 2
.
.
Stn N
Utility 1
Bilaterals & PXs
Utility 2
.
.
Stn N
1
2
3
96
Figure in MW
Form D : Format for Schedule of drawl by Constituents
Stn 1
EX-PP
Tm Pt.
Blk
Stn 2
EX-PP
.
EX-PP
.
EX-PP
Stn N
EX-PP
LOSS
For Date
DEBIT
FOR
ISGS
WHEEL
BILAT
TOTAL
IEX
TOT.
PXI
TOT.
NET
DRAWAL
SCHD.
1
2
.
.
.
.
.
.
96
112 | P a g e
ERLDC: POSOCO
Format for Schedule of Ex PP Generation
TmPt.
Blk
For Date:
AVL
SCHD
AVL
SCHD
AVL
SCHD
AVL
SCHD
AVL
SCHD
StN1
Stn1
Stn2
Stn2
.
.
.
.
StnN
StnN
(Ex-PP)
(Ex-PP)
.
.
.
.
( Ex-PP)
(Ex-PP) ( Ex-Bhu)
(Ex-Bhu)
UnReq
UnReq
SurplusStn1 SurplusStnN
(Ex-PP)
(Ex-PP)
1
2
96
113 | P a g e
ERLDC: POSOCO
Annexure: XX
Meter Locations
BHUTAN
METER LOCATIONS IN C. SECTOR
INTER-CONNECTED SYSTEM
B’SARIFF (M)
B
BI-01,BI-02,BI-67
BODHGAYA (S)
BI-15,BI-16
MADHEPURA (S)
BI-05,BI-06
PURNEA (S)
BI-03,BI-04,BI-51
KISHANGANJ (S)
BI-20
KHAGUAL (S)
BI-13,BI-14
ARAH (S)
H
BI-11
DUMRAO (S)
BI-12
J’PUR (S)
BI-19
BANKA (S)
BI-58
NEW PUSAULI (S)
BI-32
NEW PUSAULI (S)
BI-33
C
SABOUR (S)
BI-59
L
SABOUR (S)
BI-07
K’GAON (S)
BI-10
DEHRI (S)
S
P
BI-62
MOHANIA(S)
BI-49
KUDRA (S)
BI-50
HAJIPUR (S)
BI-52,BI-53
KANTI (S)
BI-68,BI-69
KHAGAUL(S)
BI-22
FATUAH (S)
BI-23
SIPARA (S)
BI-24,BI-25
DEHRI (S)
BI-17,BI-18
LAKHISARAI (S)
BI-30, BI-31
JAMUI (S)
BI-26, BI-27
SULTANGANJ(S)
BI-28,BI-29
B’
D
E
S
H
N
E
P
A
L
BHERAMARA (S)
T/C
D/C
T/C
D/C
(M) GAYA
EP-13,EP-14
(M) PURNEA
EP-83,EP-84
(M) PURNEA
ER-62,ER-63,ER-48
(M) PURNEA
ER-49
(M) ARAH
EM-72,EM-73
(M) ARAH
ER-09
(M) ARAH
ER-10
(M) ARAH
EP-27
(M) BANKA
EP-52
(M) ARAH
ER-94
(M) PUSAULI
ER-14
(M) BANKA
EP-53
(M) K’GAON
D/C
D/C
D/C
D/C
D/C
D/C
D/C
KH-13
(M) K’GAON
KH-19
(M) PUSAULI
ER 55
(M) PUSAULI
ER-79
(M) PUSAULI
ER-78
(M) MZ’PUR
ER-56,ER-57
(M) MZ’PUR
EM 31,EM-32
(M) PATNA
EM-65
(M) PATNA
EM-64
(M) PATNA
EP-46,EP-47
(M) GAYA
EP-15,EP-16
(M) LAKHISARAI
EN-51,EN-52
(M) LAKHISARAI
EN-89,EN-90
(M) BANKA
EN-83,EN-84
(M) B’PORE
EP-93
EP-95
DHALKEBAR
EP-95
NE-84
NE-88 (C)
(S) B’SARIFF
ER-01,ER-02,ER-03
D/C
GALEGPHU/
MOTUNGA
MUZ’PUR
ES-09
C.
S
E
C
T
O
R
E
R
/
I
P
P
NE-83 (M)
NE-87
BINAGURI (M)
Q/C
ER-37,ER-21,
EN-06, EN-07
BIRPARA (M)
ER-42,ER-43
(S) B’GAON
NE-85,NE-86,
NE-89, NE-90
D/C
(S) SALAKATI
NE-81,NE-82
N
E
R
B’SHARIFF(E) (M)
(S) SASARAM (N)
ER 82, ER-83
BRBCL (M)
EP-23,EP-24
PUSAULI ICT
ER-94,ER-97
PUSAULI (M)
ER-56
GAYA(M)
EP-19,ES-26
MUZ’PUR (M)
EM-25, EM-26
B’SF (M)
EM-21, EM-22
PATNA (M)
(S) SAHUPURI
D/C
NR-03
(S) VARANASI
NR-19,NR-20
(S) GORKH’PUR
D/C
NR-11, NR-12
(S) BALIA
D/C
NR-13, NR-14
(S) BALIA
EM-53, EM-57
EP-42, EP-43
BIHARSHARIFF(M) D/C
EP-03, EP-04
BARH (M)
D/C
BH -18,EM-20
(S) VARANASI
NR-22, NR-23
(S) GORKH’PUR
NR-09, NR-10
(S) D’GARH
EN-42,EN-41
CS-02, CS-03
EP-66,EP-68
STERLITE (M)
ST-09,ST-14
RANCHI (M)
EM-47,EM-48
N. RANCHI (M)
EN-10
EN-99
GAJUWAKA (M)
ER-84
ER-85
D/C
D/C
D/C
D/C
R
NR-01, NR-02
NR-15,NR-16
SUNDERGAR (M)
SUNDERGAR (M)
N
(S)RAIGARH
CS-57,CS-62
(S)RAIGARH
CS-58,CS-63
W
R
(S) SIPAT
CS-60,CS-61
(S) D’GARH
CS-01
CS-04
(S) GAJUWAKA
DC-03
DC-04
S
R
765 kV
400 KV
220 KV
132 KV
(M) ---- MAIN
(S) ---- STANDBY
114 | P a g e
ERLDC: POSOCO
METER LOCATIONS IN C. SECTOR
INTER-CONNECTED SYSTEM
TARKERA (S)
G
R
I
D
C
O
D/C
(M) ROURKELA
OR-01,OR-02
KATAPALI(M)
ER-23,ER-24
(S) BOLANGIR
OR-17
SADEIPALI(M)
ES-22
(S) BOLANGIR
OR-18
M’MUNDALI (M)
OR-08,OR-14
M’MUNDALI (S)
D/C
D/C
ES-23
(S) ANGUL
EP-71,EN-32
(M) TALCHER
TL-11,TL-12
(S) BARIPADA
OR-09,OR-10
M’SHAL (M)
OR-20
RENGALI (S)
OR-11
RENGALI(S)
D/C
OR-03,OR-04
J’NAGAR(S)
D/C
(M)
EM-88
TALCHER
(M)
TL-10
RENGALI
ER-30,ER-31
(M)JEYPORE
ER-34,ER-35
(M)I’VATI
OR-05,OR-06
I’VATI(S)
OR-13
BALASORE (S)
D/C
ER-86
(M) BARIPADA
OR-60,OR-63
BARIPADA (S)
ER-20,EM-58
(M) BARIPADA
OR-61
ER-98
(M) BARIPADA
R’RANGPUR(S)
(M)
ER-99
TALCHER
(M)
TL-09
TALCHER
OR-62
TTPS (S)
OR-12
M’MUNDALI
(S)
TL-09
(S) BARIPADA
OR-07
DUBURI (M)
EM-89
OR-22
S
I
K
K
I
M
(S) RANGIT
RAVANGLA(M)
RG-07
SM-01
(S)SILIGURI
MELLI (M)
ER-57
SM-02
(M)RANGIT
SAGBARI
EM-03,EM-05
GANGTOK ICT
R’CHANDRAPUR (M)
JS -01,JS-02
D/C
D/C
DUMKA (S)
JS -09,JS-10
J
S
E
B
RG-10
D/C
CHAIBASA (S)
JS -11,JS-12
LALMATIA (S)
D/C
(S)JAM’PUR
ER-17,ER-18
(M) MAITHON
EN -87,EN-88
(M)CHAIBASA
EN -97,EN-98
(M) K’GAON
KH-14
(M) FARAKKA
JS-03
LALMATIA (S)
JS-04
HATIA (S)
JS-06,JS-07
CHANDIL (S)
EM-03,EM-05
D/C
FK-14
(M) RANCHI
EN-96,EM-44
(M) RANCHI
JS-05
EM-45
400 KV
220 KV
132 KV
(M) ---- MAIN
(S) ----- STANDBY
C.
S
E
C
T
O
R
E
R
/
I
P
P
DALKHOLA (M)
EP-55,EM-96
BIRPARA (M)
ER-44,EM-75
SILIGURI (M)
ER-52,ER-53
S’GRAM (M)
EP-72,EP-73
B’PORE (S)
EN-68,EN-69
FARAKKA (S)
FK-16
DURGAPUR (S)
EM-91,EM-20
MALDA(M)
ER-58,ER-59
S’GRAM(M)
EN-16,EN-17
DURGAPUR (S)
ER-68,ER-08
S’GRAM (S)
EM-74
S’GRAM (M)
D/C
D/C
D/C
D/C
(M) S’DIGHI
D/C
WB-25,WB-27
(M) S’DIGHI
WB-12
(M) S’DIGHI
WB-14,WB-21
(S) MALDA
D/C
WB-05,WB-06
HALDIA
D/C
D/C
D/C
EM-18,EM-19
S’GRAM (S)
EM-17
SILIGURI(M)
W
B
(M) B’NAGAR
WB-19,WB-20
(M) S’DIGHI
WB-13
S’GRAM
(M) JEERAT
WB-09
(S) K’SEONG
S
E
WB-58
ER-54
RANGIT(M)
RG-04
B’GURI (M)
(S) DALKHOLA
WB-18,WB-16
(S) BIRPARA
WB-01,WB-02
(S) NBU
WB-03,WB-04
EM BYPASS
(S) K’SEONG
D/C
ER-19,ER-45
CHAIBASA (S)
ES-30,ES-29
RANGIT (M)
WB-57
J’GURI
(M)KOLAGHAT/K’PUR
B
WB-30,WB-29
(S) R’MAM
WB-11
(M) JEERAT
WB-08
(M) KHARAGPUR
RG-06
B’PORE (S)
EP-89
BARIPADA (S)
ER-27
S’GRAM (M)
WB-17
N.TOWN, BANTALA
EN-61,EN-62
GAYA (S)
D/C
EN-48,EN-70
(M) KODERMA
DV-40,DV-42
B’SHARIFF(S)
D/C
EP-25,EP-26
MAITHON (S)
T/C
(M) KODERMA
DV-20,DV-21
(M) MEJIA
EM-97,EM-98,ER-15
MAITHON (M)
D/C
DV-04,DV-24,DV-25
(S) DHANBAD
ER-11,ER-12
MAITHON (M)
D/C
DV-18,DV-19
(S) K’SWARI
EM-80,EM-81
JMS’PUR (S)
D/C
DV-08,DV-09
(M) DSTPS
EP-20,EP-21
DURGAPUR (M)
EM-05,ER-06
BARIPADA (S)
EM-86
JAMSHEDPUR (S)
EM-86
MAITHON (S)
DV-10,DV-06
(S) PARULIA
DV-01
V
C
(M) TISCO
DV-34
(M) TISCO
DV-35
EP-22
(M) RTPS
DV-36
RANCHI (S)
(M) RTPS
EM-41
D
DV-38
115 | P a g e
ERLDC: POSOCO
METER LOCATIONS IN BSPHCL
INTER-CONNECTED SYSTEM
D/C (M) GAYA
EP-13,EP-14
T/C
(S) B’SARIFF
BODHGAYA (S )
BI-15,BI-16
B’SARIFF (M)
BI-01,BI-02,BI-67
ER-01, ER-02,ER-03
NEW PUSAULI (S)
(M)ARAH
ER-94
BI-32
NEW PUSAULI (S)
TENUGHAT
J
S
E
(S)
(M)
JS 62
(S)
LALMATIA
(M) KAHALGAON
JS 63
JAPLA
BI-09
(S)
(M)
SONENAGAR
(M)
SULTANGANJ
W
B
D
V
DEOGARH
(S)
JS 65
KISHANGANJ
BI-21
WB 52
(M)
BARHI
(S)
DV 51
(M)
NR 07
BI 66
CHANDAULI
(S)
(M)
NR 06
SAHUPURI
BI 56
H
KARMNASA
BI 63
(S)
(M)
NR 05
400 KV
220 KV
132 KV
(M) ---- MAIN
(S) ---- STAND BY
D/C
LAKHISARAI (S)
(M) LAKHISARAI
EN-51,EN-52
BI-30,BI-31
MADHEPURA(S)
BI-05,BI-06
PURNEA (S)
BI-03,BI-04,BI-51
KISHANGANJ(S)
BI-20
D/C
(M) PURNEA
T/C
(M) PURNEA
EP-83,EP-84
ER-62,ER-63,ER-48
(M) PURNEA
ER 49
ARAH (S)
BI 11
DUMRAO (S)
BI 12
KHAGAUL (S)
D/C
JAGDPUR (S)
ARAH
EP 27
(M) BANKA
EP 52
EP 53
(M) K’GAON
KH 13
(M) K’GAON
C
KARMNASA
BI 64
L
D/C
(M) LAKHISARAI
EN-89, EN-90
(S) MUZ’PUR
EM-31,EM-32
KHAGAUL (S)
BI-22
FATUAH (S)
(S)
(M) MUZ’PUR
EP-56,EP-57
D/C
BI-26, BI-27
KANTI (M)
BI-68,BI-69
BI-23
SIPARA
S
E
C
T
O
R
KH 19
PUSAULI
ER 79
(M) PUSAULI
ER-55
(M) PUSAULI
ER-78
BI-50
JAMUI (S)
ARAH
ER 09
(M) ARAH
ER 10
(M) ARAH
EM-72,EM-73
(M)
BI-19
BANKA (S)
BI 58
SABOUR(S) BI 59
SABOUR (S)
BI 07
K’GAON (S)
BI-10
MOHANIA
BI 49
DEHRI (S)
HAJIPUR (S)
BI-52,BI-53
C
E
N
T
R
A
L
(M)
BI-62
KUDRA (S)
(M) SONENAGAR
RIHAND (S)
N
R
BI 48
RAJGIR
BI 55
BSF
C
P
NALANDA
(M)
ER-14
BI-33
BI-13,BI-14
BI 61
DALKHOLA
BARHI
S
BI 60
JS 64
B
B’SF
BI 57
B
(M)PUSAULI
(M) PATNA
EM 65
(M) PATNA
D/C
EP-46,EP-47
BI-24,BI-25
SULTANGANJ (S)
BI-24,BI-25
DEHRI (S)
BI-17,BI-18
EM 64
(M) PATNA
D/C
(M) BANKA
D/C
(M) GAYA
BI-24,BI-25
EP-15,EP-16
116 | P a g e
ERLDC: POSOCO
METER LOCATIONS IN JUVNL
INTER-CONNECTED SYSTEM
B’SF
B
S
E
B
WB
SEB
D
V
C
G
R
I
D
C
O
N
R
(M) TENUGHAT
(S)
BI 57
JS 62
K’GAON (S)
BI 60
SULTANGANJ (S)
BI 61
WB 53
JS 63
(M) JAPLA
JS 64
(M) DEOGARH
JS 65
(M) CHANDIL
(M)JAMTARA
DV 56
PATRATU
DV 53
JS 66
(M) PATRATU
JS 54
JS-53
JODA (S)
OR 52
RIHAND (S)
NR 08
R’CHANDRAPUR (M)
JS 02
DUMKA (S)
JS 09,JS-10
U
V
JS 40
JODA (S)
OR 53
GOELKERA (S)
ER 17
(S) JAM’PUR
ER 18
D/C
(M) MAITHON
EN-87EN 88
CHAIBASA (S)
D/C (M) CHAIBASA(S)
JS-11,JS-12
EN-97,EN-98
LALMATIA (S)
(M)
JS 57
MAITHON(S)
MANIQUE
DV 55
(S) JAM’PUR
JS 01
(M) LALMATIA
BI-09
SONENAGAR (S)
SANTALDIH (S)
J
R’CHANDRAPUR (M)
K’GAON
KH 14
JS 03
LALMATIA (S)
(M) FARAKKA
JS 04
FK 14
(M) CHANDIL
C
E
N
T
R
A
L
S
E
C
T
O
R
JS 56
(M) RAMCHANDRAPUR
JS 51
(M) ROURKELA
OR-51
N
(M) KENDPOSI
D/C
JS 05
(M) GARWA
L
(M) RANCHI
EN-96,EM 44
CHANDIL (S)
JS 52
JS 58
HATIA (S)
JS-06,JS 07
(M) RANCHI
EM 45
400 KV
220 KV
132 KV
(M) ---- Main
(S) ----- Stand by
117 | P a g e
ERLDC: POSOCO
METER LOCATIONS IN DVC
INTER-CONNECTED SYSTEM
KODERMA (M)
B
S
E
B
(S) MAITHON
EP-50,EP-51
DV-40,DV-42
RAJGIR
(S)
(M) BARHI
RTPS (M)
DV 51
BI 55
(S) MAITHON
EP 22
DV-36
NALANDA(S)
BI 56
(S) BARIPADA
TISCO (M)
DV-34
EM 86
(S) JAMSHEDPUR
DV 35
D
W
B
S
KOLAGHAT
(S)
WB 54
(S) MAITHON
DV-24,DV-25,DV-05 EM 97,EM-98,EM-76
(M) KOLAGHAT
DV 61
BIDHANNAGAR
WB 51
EP 44
T/C
MEJIA (M)
(S)
(M) WARIA
DV 60
V
PARULIA
DV 01
(S)
(M) Durgapur
D/C
ER 05
ER 06
DV 64
E
C
B
(S) JAMSHEDPUR
MEJIA (M)
EM 76
(S) RANCHI
DV 05
RTPS (M)
EM 41
DV 38
DHANBAD (S)
(M) MAITHON
ER 11,ER-12
DV-18,DV-19
KALYANESWARI(S)
DV 08,DV-09
G
R
I
D
C
O
J
S
E
B
(M) MAITHON
EM 80,EM-81
KODERMA (M)
JINDAL
(S)
(M) JAMSHEDPUR
DV 57
OR 54
(S) GAYA
EN-48,EN-70
DV-40,DV-42
KODERMA
(S)
(M) BSF
DSTPS(ANDAL)_
(M)
(S)
(M) PATRATU
DV 53
JS 40
CHANDIL (S)
JS 56
JAMTARA
JS 66
(S)
(S) JAMSHEDPUR
DV 06
EP 20
DV 10
EP 21
RAGHUNATHPUR(M)
DV 36
DV 38
S
E
C
T
O
R
EP 25,EP-26
DV 20,DV-21
PATRATU
JS 54
C
E
N
T
R
A
L
(S) MAITHON
EP 22
EP 78
(S) RANCHI
(M) MANIQUE
DV 55
(M) MAITHON
DV 56
400 KV
220 KV
132 KV
(M) ---- Main
(S) ----- Stand by
118 | P a g e
ERLDC: POSOCO
METER LOCATIONS IN GRIDCO
INTER-CONNECTED SYSTEM
RAMCHANDRAPUR
J
S
E
B
D
V
C
(S)
(M) JODA
JS 51
OR 53
KENDPOSI
(S)
(M) JODA
OR 52
JS 52
GOELKERA (S)
(M) ROURKELA
JS 53
OR 51
JAMSHEDPUR(S)
(M) JINDAL
DV 57
G
R
I
OR 54
D/C (M) ROURKELA
TARKERA (S)
ER-23,ER-24
OR-01,OR-02
(M) BOLANGIR
KATAPALLI(S)
OR 17
ES 22
(M) BOLANGIR
SADEIPALLI(S)
ES 23
OR 18
(S) ANGUL
MERAMUNDALI (M) D/C
OR-14,OR-08
EP-71,EN-32
MERAMUNDALI(S)
OR-09,OR-10
(S) BARIPADA
OR-20
DUBURI (M)
EM-88
(S) BARIPADA
OR-22
EM-89
MERAMUNDALI(M)
OR-07
RAIGARH (S)
CS 56
KORBA
(M) BUDHIPADAR
OR 56
(S)
(M)BUDHIPADAR
(S)
(M)BUDHIPADAR
OR 57
CS 54
S
R
(S) TSTPP
TL-18
D
C
R
(M) TSTPP
TL-11,TL-12
MENDASAL (M)
RENGALI PH
OR-11
W
D/C
KORBA
CS 55
U. SILERU (M)
OR 59
(S) BALIMELA
DC-05
400 KV
220 KV
132 KV
(M) ---- MAIN
(S) ---- STAND BY
OR 15
O
(S)
TALCHER TPS (S)
OR-12
RENGALI (S)
OR-03,OR-04
(M) TSTPP
TL-10
(M) TSTPP
TL-09
S
E
C
T
O
R
(M) RENGALI
ER-30,ER-31
JAYANAGAR (S)
OR-05,OR-06
(M) JEYPORE
INDRAVATI (S)
OR-13
(M) INDRAVATI
BALASORE(S)
OR-60,OR-63
(M)BARIPADA
BARIPADA (S)
OR 61
R’RANGPUR(S)
OR 62
(M)BARIPADA
(S)
(M)BARIPADA
BALASORE
C
E
N
T
R
A
L
ER-34,ER-35
ER-86
ER-20,EM-58
ER 98
(M)BARIPADA
ER 99
EM 66
119 | P a g e
ERLDC: POSOCO
METER LOCATIONS IN WBSETCL
INTER-CONNECTED SYSTEM
(M) DALKHOLA
DALKHOLA(S)
WB-16,WB-18
S
I
K
K
I
M
J
S
E
B
B
S
E
B
MELLI (S)
SM 51
V
C
66 kv
W
WB 59
B
BIRPARA (S)
WB-01,WB-02
(M) BIRPARA
ER-44,EM-75
(M) S’GRAM
EN-16,EN-17
(M) NJP
HALDIA
NBU(S)
WB-04,WB-03
EM BY PASS(S)
ER-52,ER-53
(M) S’ GRAM
EP-72,EP-73
S’ GRAM
EN 62
S’ GRAM
EN 61
(S) FARAKKA
NEW TOWN
BANTALA
CHANDIL(S)
JS 57
(M) SANTALDIH
WB 53
S
KISHANGANJ(S)
BI 21
(M) DALKHOLA
B
KOLAGHAT
WARIA(S)
(M) BIDHANNAGAR
DV 64
WARIA (S)
DV 60
WB 54
(M) BIDHANNAGAR
WB 51
FK 16
(M) MALDA
ER-58,ER-59
(S) B’RAMPORE
ER-68,ER-69
SAGARDIGHI (M)
WB-25,WB-27
B’NAGAR (S)
(M) DURGAPUR
ER 07
WB-07
WB 52
DV 61
SAGARDIGHI (M)
WB-12
MALDA (S)
WB-05,WB-06
E
KOLAGHAT(M)
D
(M) KALINGPONG
EM-96,EP-55
EP 89
(S) BARIPADA
KHARAGPUR(M)
WB 17
ER 27
RAMAM (M)
WB-11
NEW JALPAIGURI(S)
(S) RANGIT
RG 06
(M)BINAGURI
ER-45,ER 19
KURSEONG(M)
WB-57
KURSEONG (M)
WB-58
JEERAT (M)
WB-09
S’GRAM(S)
D/C
(S) RANGIT
RG 04
(S) SILIGURI
ER 54
(S) SUBHASGRAM
EM 17
(M) SUBHASGRAM
EM 18,EM-19
(S) CHAIBASA
ES 29
WB 29
KOLAGHAT(M)
WB 30
SAGARDIGHI(M)
WB-13
SAGARDIGHI(S)
WB-14,WB-21
MAIN
STAND BY
S
E
C
T
O
R
(S) B’RAMPORE
JEERAT (M)
WB-08
KHARAGPUR(M)
400 KV
220 KV
132 KV
(M) ----(S) -----
C
E
N
T
R
A
L
BIDHANAGAR(S)
WB-19,WB-20
(S)
(S) CHAIBASA
ES 30
SUBHASGRAM
EM 74
(M)DURGAPUR
EM-91,EM-20
(M) DURGAPUR
ER-08,ER-68
120 | P a g e
ERLDC: POSOCO
METER LOCATIONS IN SIKKIM
INTER-CONNECTED SYSTEM
C
H
E
P
S
CHUZACHEN
MELLI
CZ-05
SM 03
I
66 kV
SM 01
RG 07
RAVANGLA (M)
(S) RANGIT
GYALSHING
SAGBARI
SM 07
W
B
S
E
B
K
KALIMPONG(S)
WB-59
66 kv
(M) MELLI
I
SM 05
(S)
MELLI
(M)
RG 10
(S) NJP
SM 02
ER 57
EM 04
EM 06
M
(M) RANGIT
132 kV
SM 04
SM-51
K
400 KV
220 KV
132 KV
(M) ---- MAIN
(S) ----- STAND BY
MELLI
SM 06
C
E
N
T
R
A
L
EM 03
132/66
S
E
C
T
O
R
EM 05
GANGTOK
121 | P a g e
ERLDC: POSOCO
METER LOCATIONS IN CENTRAL SECTOR TRANSMISSION SYSTEM
PART-I
MELLI
GYALSHING
CU06 CU 07
CU05
RG 01 RG02 RG03
RANGIT
CHUKHA
CU 08
TALA
SAGBARI
SINGHIGAON
TH-01 TH-02 TH-04
RG-10
CU 03
CU 01
CU02
RG 04
RG-11
RG06
RG 07
RAMAM
EM02
RG08
EM01 EM 03
EM 04
RAVANGLA
TS01 TS01 TS03
TEESTA
MALBASE
BIRPARA
EM-67
ER 41
ER 47
ER 39
ER 40
ER 22
EM-11
EM-12
EM-13
EM-14
K’ SEONG
ER76
ER-57
KISHENGANJ
ES-16
ES-17
ER-50
ER-51
ER 53
ER52
ES-18
ES-19
ER-46
NJP (WBSEB)
GORAKHPUR
BONGAIGAON
BINAGURI
ER-47
SILIGURI
ER-54
NE 85
NE 86
ER 23
BINAGURI
JL-03
JLHEP
SALAKATI
ER 42
ER 43
ER 37
EM 7 EM 8 EM 10 EM 9
EM-68
EN-85
EN-86
JL-05
EM 75
ER 46
MELLI
TS-05
TS-06
N. MELLI
BT33
BT40
BIR(W)
ER 44
CZ-02 CZ-01
CZ-07
SM03
RANGPO
BT34
BT35
EM 06
GATI
CZ-05
BT36
BT 39
EM 05
CZ-03
66 kV
BT38 BT37
GANGTOK
ES-11
ES-12
NBU
EM25
EM26
MUZAFFARPUR EM23
EM27
EM24
EM28
PURNEA
EM29
EM30
Madhepura
ER 65
ER 63
KANTI(B)
HAJIPUR
Dhalkebar(Nepal)
EP-92
ER-88
ER 09 / 4153A
EP-85
EP-86
ES-09
ER 62
411A
ER 64
ER 49
DALKHOLA
PUR(B)
BALIA
K’GANJ
EM-96
EP-55
WB-16
WB-18
WB-52
SASARAM (N)
ALLAHABAD
MALDA(W)
VARANASI
ER 78
KARMANASA
EP-23
EP-24
ER 56
PUSAULI
NEW
BANKA
ER 10
J’Pur
ARRAH
EP-74
EP-75
BI 13
BI 14
KHAGAUL
DUMRAO
Sipara
L’SARAI EN-47
EN-27
EN-89
EN-90
EN-26
EN-46
EN-51
EN-52
BANKA
KH-31
KH-32
KH 35 KH 36
EM 56
EM 55
EM 57
ER 88
EM 53
KG 03 KG 02 KG 01
ER 01
VARANASI
B’SHARIFF(BSEB)
LAKHISARAI
KH-11
KH-12
KH 01 KH 02 KH 03 KH04
EM 54
TENUGHAT
KAHALGAON
KH 07
KH 08
KH 15
KH 14
GORAKHPUR(NR)
BH-18,BH-20
BH-04
BH-05
BH-03
BH-02
MAITHON
KH 17 KH 18
KH 05 KH 06
SABOUR
BH-06
BH-07
BH-08
BH-10
KAHALGAON(B)
KH 16
KH 19
KH 13
PATNA
BALIA
NR 02
MALDA
BIHARSHARIFF
ER 02
KH 10 KH 09
FATUA
ER 59
ER 58
ER 60
EP-25
EP-26
EP-04
JAMUI ER 03
KODERMA
(DVC)
ER 61
EM-21
EM-22
EN-01
EN-02
ER-89
ER-90
ARAH ER 94
ER 9
GAYA
ER-82
ER-83
N’Nagar
ER 14 ER 13
ER 55
DEHRI
EP-19
ES-26
SASARAM (E)
ER 79
SAHUPURI
NR 01
DALKHOLA(WB)
F’PUR
KUDRA
ES-20
ES-21
LALMATIA
BS 09
FARAKKA
BARH
122 | P a g e
ERLDC: POSOCO
PART-II
LALMATIA(JSEB)
KAHALGAON
HATIA
MPL RB
CHANDIL
MALDA
FK14
SIPAT
EN-96
EM 44
EM 45
RANCHI
EM 46
EN-03
EN-05
EN-08
EN-09
FK 01 FK 02
ER16
TIE
TRA
FK 06 FK 07 FK 18
FK-30
FK 05
B’ PORE
ER 07
ER 68
EP-05
EP-06
ER70
ER69
FK 03 FK 04
FARAKKA
FK 16
SAGARDIGHI
EN-87
EM-85
EN-88
EM-84
MAITHON
EM 97
EM-98
FK15
DUMKA
EM 41
RTPS(DVC)
EM-82
EM-83
FK 13
FK 10
FK 11
K’GAON
EM 42
FK17
FK 08
FK 09
EM 43
DURGAPUR
ER 66
ER 11 ER 12 EM 80 EM 81
BHERAMARA
BANGLADESH
B’NAGAR(WB)
ER 67
MEJIA
DHANBAD
(DVC)
NEW
RANCHI
K’SWARI
(DVC)
KODERMA
(DVC)
DSTPP (ANDAL)
ER 06
ER 05
WB-14
PARULIA
WB 08
EP-20
EP-21
EN-10
EN-99
JEERAT
JAMSHEDPUR
D’jaygarh(WR)
EN-56
EN-56
ER 08
ER18
HALDIA
ER 17
AP-03
AP-04
BS 05
BS 06
CHAIBASA
APNRL
AP-02
AP-01
BANTALA EM 17
KOLAGHAT
RC PUR
KHARAGPUR
ER 71
ER 72
ROURKELA
DUBURI (GR)
S’GRAM(W) EM
ER-80
ER 23
BYPASS
ER 27 BARIPADA
ER 81
EM 93
ER 24
EM 16
EM 18
SUBHASGRAM
CHBA
ER 25
WB 09
EM 15
WB 10/476A
ER 26
SAGARDIGHI
MEDHASHAL(GR)
EM 69
TATA
TISCO
S’GARH
NEW TOWN
BALASORE(GR)
TARKERA
RAIGARH
RENGALI(G)
ST 09
ST 14
STERLITE
ER 30
ER 31
ER 73
ER 74
BARIPADA(GR)
RAIRANGPUR(GR
KEONJHAR
IBEUL
ST 13
ST 10
RAIGARH(WR)
STG-II
TL05
TL06
TL07
TL 02
TL 13
TL 01
TL 11
TL 12
TL 10
TTPS
TL 09
TALCHER STPP
JEYPORE
ER 36
ER 85
ER75
ER 84
400 KV
220 KV
132 KV
MERAMUNDALI
OR 08
OR 14
OR-07
ER77
ER 34
TL 04
ER 86
INDRAVATI PG
RENGALI PS
TL-14
TL-15
TL08
TL 28 TL 03
INDRAVATI PG
BALASORE(GR)
RENGALI
ER29
469A
D’jaygarh(WR)
ER 28
ER 35
GAJUWAKA(S)
DC-3
SR
JD-02
DC-4
GAJUWAKA(E)
SR
JINDAL
JD-05,JD-03
GM-09,GM-11
JEYNAGAR
KATAPALLI
SADEIPALLI
BOLANGIR
ANGUL
EN-78
EM-95
GM-10
S’GARH
123 | P a g e
ERLDC: POSOCO
Annexure :XXI
Grid Maps
124 | P a g e
ERLDC: POSOCO
125 | P a g e
ERLDC: POSOCO
126 | P a g e
ERLDC: POSOCO
127 | P a g e
ERLDC: POSOCO
128 | P a g e
ERLDC: POSOCO
129 | P a g e
ERLDC: POSOCO
130 | P a g e
ERLDC: POSOCO
131 | P a g e
ERLDC: POSOCO
132 | P a g e
ERLDC: POSOCO
Annexure :XXII
Message for violation of TTC/Flow Gate/System Constraint.
Eastern Regional Load Despatch Centre
POWER SYSTEM OPERATION CORPORATION
14 Golf Club Road, Tollygunge, Kolkata 700033
Tel.: 033-24235435, FAX: 033-24235809 web:www.erldc.org
FAX MESSAGE
Reference: ERLDC/OPRN/SYSCON/_____
FROM:
SCE , ERLDC, KOLKATA
TO:
SCE : (concerned LDC / ISGS)
Date :_________
TOO :______
Copy To:
Sub:
Immediate action for measures detailed below on violation of TTC/Flow Gate/System
constraint.
At present the Deviation of your control area/ISGS is as follows:
Regional entity /
Schedule
Actual
Overdrawal/Overgeneration(+)/
Region
Underdrawal/Undergeneration(-)
The following TTC limits are getting violated at present:
The following flow gate alarms have come:
Name of Flow Gate
Name
Actual
The following lines are presently critically overloaded:
Name of the line
Limit
Power Flow (MW)
<Action to be taken>
Remark:
SHIFT CHARGE ENGINEER
ERLDC/KOLKATA
133 | P a g e
ERLDC: POSOCO
Annexure :XXIII :- Format for Applying and Withdrawing congestion
134 | P a g e
ERLDC: POSOCO
135 | P a g e
ERLDC: POSOCO
136 | P a g e
ERLDC: POSOCO
Document Management Information:
Document Name
Document ID
Rev No.
Classification
Operating Procedures for Eastern Region
ERLDC/OP/2015-16/Rev 11
11
Date
31st July 2015
Public
Document Modification History
Revision No
00
01
Date of Revision
31.10.2008
08.12.2008
Remarks
02
31.10.09
03
29.10.10
04
31.12.10
1) All the annexures updated.
05
31.03.2011
1) All the annexures updated.
06
20.05.2011
1) All the annexures updated.
07
29.05.2012
08
28.06.2013
09
26.07.2013
10
31.7.2014
11
31.07.2015
1) Chapter 6 flow gates are reviewed.
2) Chapter 7 scheduling and despatched
procedure revised.
3) All the annexures are updated
1) Chapter 2 Frequency control is reviewed
2) Chapter 3 Voltage control is reviewed
3) Chapter 5 Switching coordination is
introduced
4) Chapter 7 flow gate are reviewed
5) Chapter on Water supply system at
ERLDC is deleted,
6) All annexures are revised
1)Chapter 4 outage planning is reviewed
2) Annexure- I, II, III, VII & XV is updated
as per information received from WBSLDC
1) Frequency Band Updated
2) Annexures Updated
3) Flow gate reviewed
1) Annexures Updated
Annexure XXIV ( schedule of Regional
Transmission Assets) added at Page 118120
1) Chapters 1 to 7 and 9 revised in line with
the draft IEGC (under consideration by
CERC for implementation w.e.f
01.01.2010). All annexures updated &
Annex- XXV (Message format for violation
of TTC) added
2) Chapter 10 for Water Supply system
included
1) Chapters 1 ,2,3 and 6 revised in line with
new IEGC (implemented from 03.05.2010)
2) Chapters 7 and 8 are revised.
137 | P a g e
ERLDC: POSOCO
2) Flow gate reviewed
12
04.07.2016
1. Chapter 2,3,4,5,6,7,8,9,10 Updated
2. Annexures Updated
138 | P a g e