handbook-grid code

OPERATING PROCEDURES FOR EASTERN REGION

(as mandated by the IEGC clause 5.1(d))

Revision No: 01 Dated 8th Dec’08

Eastern Regional Load Despatch Centre 14,Golf Club Road, Tollygunj

Kolkata – 700033

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Index of Contents

Sl No Chapter Page No 1 General 3 2 Frequency Management 5 3 Voltage Management 9 4 Outage Planning 12 5 Periodic Reporting and Event information 16 6 Network Security and Congestion

management 19

7 Scheduling and Despatch 29 8 SCADA system operation 36 9 Metering & Settlement System 62

List of Annexures

_________________________________________________________________________ Operating Procedures for Eastern Region Page 1 15-12-2008

No. Annexures Page No

I Generation Capacities in Eastern Region 64 II List of Generating Stations and their Capacities 65 III Captive Generating Stations in ER and their capacities 68 IV UI Rate at different frequencies 69 V Variable Cost of Thermal Generating stations in ER and the

Cumulative Installed Capacity 70

VI Category ‘A’, Category ‘B’ and Category ‘C’ messages 71-73 VII General Message for curtailment of overdrawal 74 VIII List of 400/220kV ICTs and their tap positions 75 IX Reactive Compensation details at 400kV S/S and Lines 76 X Format for message to be issued by ERLDC for Real Time

Outage clearance 77

XI Format for Weekly Report 78 XII Format for Quarterly Report 80 XIII Format for Event Reporting 81 XIV Categorisation of Grid Incidents and Grid Disturbance 82 XV ER Flow gates 83 XVI List of Important elements in ER 87 XVII Automatic UFR Load shedding schemes 93 XVIII PDOs ta Gazuwaka, Talcher and Kolar 94 XIX Special Protection schemes at Talcher

( SPS 450 & SPS 1000) 95

XX Existing Islanding Schemes 97 X XI Format for schedules 98 XXII Metering Schemes 101 XXIII Grid Maps 111 XXIV Schedule of transmission assets of ER grid 118 XXV List of External Documents ( To be referred) 122

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List of Revisions: Revision No Date of Revision Remarks 00 31.10.2008 01 08.12.2008 Annexure XXIV ( schedule of Regional

Transmission Assets) added at Page 118-120


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Chapter 1 General

1.1 Introduction In compliance to the IEGC (Indian Elecricity Grid Code) clause no 5.1(d) 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 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, reliable and economic manner. 1.2 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. 1.3 Objective Objective of this document is to describe the procedures adopted for the 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 1.4 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


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1.5 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 Periodic Reporting and Event information Chapter 6 Network Security and Congestion management Chapter 7 Scheduling and Despatch Chapter 8 SCADA system operation Chapter 9 Metering & Settlement System

1.6 List of Annexures 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 documents/lists,Grid Maps etc. A list of Annexures had been shown at the beginning of this document.


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Chapter 2

Frequency Management 2.0 Frequency Standard IEGC vide its clause 5.2(l) has mandated that all Regional constituents shall make all possible efforts to ensure that the grid frequency always remains within the 49.0 – 50.5 Hz band, the frequency range within which steam turbines conforming to the IEC specifications can safely operate continuously. Frequency being 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 is a function of the load-generation balance, it is subject to variation on a continuous basis as either of the two viz. generation or load may vary from time to time. Whenever, the frequency approaches upper/lower limits of the above range, advance action needs to be uninitiated in order to arrest further rise/fall in frequency. as it takes some time for remedial measures to give desired result. Therefore, in practice, when frequency touches 50.2Hz. and is in rising trend, action shall be initiated to contain the same. Similarly, when frequency touches 49.2Hz. and is in falling trend, action shall be initiated to improve the same. 2.1 High Frequency Conditions: In case the frequency is high (above 50.2Hz) and is in increasing trend then the following actions may be initiated: 2.1.1 ERLDC shall check whether the high frequency condition is due to the heavy under-

drawal by any constituents within region or by the interregional utilities. 2.1.2 ERLDC shall advise constituents within region to lift any load shedding if any. 2.1.3 ERLDC shall explore the possibility of reducing UI import from neighbouring regions.

Alternatively, if the frequency of the southern region is lower than ER frequency, ERLDC shall explore the possibility of increasing UI export after due checking of voltage conditions and network loading. In case any major network constraint is envisaged while exporting UI to Southern Region through ER-SR HVDC links, ERLDC may in consultation with WRLDC , NRLDC and NLDC would explore the possibility of exporting UI through WR-SR HVDC link to SR.

2.1.4 ERLDC however, before reducing UI import from other region and or exporting UI to other region would check the possibility of any backing down of the reservoir based hydro stations within state system .

2.1.5 ERLDC before advising any generation reduction at the hydro stations, in consultation with concerned SLDC, would check back whether such reduction would cause any major variation in voltage levels or abnormal network loading. In such case the same shall be avoided.

2.1.6 Explore the possibility of running of Purulia Pump storage hydro units in pump mode, if levels of the upper and lower reservoirs are in permissible limits.

2.1.7 Advise/remind the states to back down costly Generation as per merit order by taking adequate support from SCADA. The applicable UI rate as revised by CERC since implementation of ABT mechanism is shown at Annexure IV List of variable cost of all thermal generators and their breakeven frequency at the existing UI rate is shown in Annexure-V.

2.1.8 If any ISGS are generating more than their schedule, advise the ISGS to reduce the over generation.


2.1.9 The Hydro stations of Bhutan power system exporting power to India are not covered commercially under ABT mechanism. Backing down advise on account of high

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frequency conditions may only 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 RLDC may attempt facilitating bilateral transaction /sale through STOA in case an utility require power. ERLDC may coordinate with NLDC for enquiring about such requirement for the states outside the region.

2.1.11 In case any constituent is underdrawing, ERLDC may advice backing down of its thermal generation as per frequency based despatch guidelines. Such advise shall be duly coordinated through concerned SLDC.

2.1.12 In case any constituent is underdrwing , ERLDC may advice concerned SLDC for considering surrendering of its share from thermal ISGS based on merit order

2.1.13 If the frequency is persisting still high, SLDCs and ISGSs thermal stations may be advised to backdown to technical minimum level with a request to explore the possibility of taking oil support till the crisis is over.

2.1.14 Backing down of the spilling hydro units or the run-off-the-river units for short duration may aldo be considered if all other options are exhausted.

2.2 Low Frequency Conditions If the frequency is less than 49.5Hz. and is on decreasing trend, the following actions may be taken: 2.2.1 If any UI export to the other region is going on, ERLDC may advice curtailment of

overdrawal in consultation with the concerned region. 2.2.2 Alternately, if the frequency of Southern Region is high, ERLDC operator would

attempt importing UI from southern region. If any major network constraint is envisaged because of such UI import ERLDC in consultation with WRLDC may explore importing of UI in the NEW Grid from southern region through SR-WR HVDC link..

2.2.3 If any Purulia Pump storage Hydro units hydro units are operating in pump mode and if the state is over drawing ERLDC shall advise advise the concerned SLDC for discontinuing the pump operation.In case the frequency is below 49.2 Hz even the under drawing constituent may be advised to stop the pump mode of operation.

2.2.4 ERLDC may advise the states to maximize their internal generation viz. hydro, thermal, IPP etc. in case the margins are available. In case Purulia Pump storage is idling , ERLDC may advice concerned SLDC for considering its operation under generation mode.

2.2.5 If any ISGS is under-generating, they may be reminded them 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 their Declared Capability.

2.2.6 The Actual receipt from the Hydro stations from Bhutan may be closely monitored under low frequency conditions. In case such generation is less than the schedule because of some technical reasons like low inflow etc., ERLDC may suo motto revise the generation schedule downwards with due downward revision of drawal schedule for the respective constituents who has 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 Un-requisitioned Surplus (URS) power from any ISGSs exists in any region, ERLDC may explore the possibility of requisitioning such surplus power by the needy states in

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the region. The same shall be informed to NLDC also in case such requirement exists outside the region.

2.2.8. If there is any generation left un despatched such as that of IPP due to cost consideration, request the state to explore the possibility to dispatch it on merit order basis.

2.2.9 If the frequency is less than 49.2 Hz. and is in falling trend, remind the overdrawing SLDC telephonically to maintain frequency by picking up internal generation, curtailing O/D, load shedding. While doing so requisite frequency correction may be applied.

2.2.10 Issue caution messages Category A, violation message Category B & Category C to overdrawing constituent/s within region as per the guidelines. if no relief is forthcoming, request them to take self regulatory measures by opening the radial feeders if possible. The broad guidelines for issuance of Category A, Category B and Category C messages is detailed below at 2.3 of this chapter

2.2.11 In the event of overdrawal by interregional constituents, 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 . Sample message format to be issued to NLDC/Other RLDCs is at Annexure VII

2.2.12 If the frequency is less than 49.0Hz and it may appear that practically no state is as such overdrawing , a general message may be issued to all states requesting to improve their generation/ shedding of loads, so that the quantum of relief may be obtained taking into consideration the frequency correction to 50.0Hz. While issuing above messages, ensure that SCADA data of the drawls is in order and there is no UI export to other region.

2.2.13 ERLDC may further examine the thermal unit outage (forced) and find out when the units are expected to be on bar and take up for expediting the same.

2.2.14 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 .

2.3 Broad Guidelines for Issue of Over drawl messages While issuing any messages, ensure that SCADA data for the drawls and injections of ISGS is in order.

1. Category A Message( Vide Annexure VI(a)) Category A Message to be issued if frequency is less than 49.5 HZ and UI is more than 100 MW. For this purpose, if more than one State is overdrawing, a single message addressing one or more overdrawing state/s can be issued.

2. Category B Message( Vide Annexure VI(b)) Category B Message to be issued under following conditions: (a) Frequency is less than 49 Hz AND UI is between 100 MW and 200 MW for more than 10 minutes Or (b) Frequency is less than 49 Hz AND UI is more than 200 MW for more than 5 minutes


For this purpose, if more than one State is overdrawing, separate message shall be given for each overdrawing state, as it is a violation message and each state is to be dealt with separately before CERC. While issuing such message the schedule and actual drawal may be clearly indicated.The Message must a clear number with date and time. The message along with the print out shall be preserved as record for all future actions such as producing

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them before the CERC etc. In case the overdrawal is by Inter regional constituent a message indicating the schedule and actual drawal by the inter regional constituents may be mentioned. It is to be noted that post -400kV Agra Gwalior interconnection between Northern and Western Region one region may be underdrawing while the other region may be overdrawing. Under such circumstances before bringing the matter to NLDC , ERLDC Operator may cross verify whether the net actual drawal is more than the net scheduled drawal at inter-regional interconnections.

3. Category C Message( Vide Annexure VI(c)) Category C Message to be issued under following conditions The over drawl is not curtailed and remains in the range of around 100 MW and/or above even after 15 minutes of issue of Message B AND Frequency is still less than 49.0 Hz. Similar procedure to be followed while issuing Category C message also as detailed above for Category B message 4. General Message when no state is overdrawing more than 100 MW

but frequency is running low: At times, the over drawal by the constituents may be less than 100 MW but frequency is less than 49 Hz. In such occasions, a general message may be issued indicating the real time values of frequency, frequency corrected drawl /frequency UI( MW restriction needed). When expected relief is not forthcoming, a general hand-written message highlighting the urgency of the matter and informing the amount of load shedding to be carried out by the constituents to lift the frequency may be issued.


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Chapter 3

Voltage Management 3.1 Introduction In compliance to the IEGC (Indian Elecricity Grid Code) clause no 5.2(r) all regional constituents shall make all possible efforts to ensure that the grid voltage always remains within the following operating range

Nominal

(KV –rms) Maximum (KV –rms)

Minimum (KV –rms)

400 420 360 220 245 200 132 145 120

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 pocket of 132kV system where radial loads are fed occasional low voltage is experienced. Post commissioning of Tala Transmission system exhaustive 400kV networks have been laid . These part of the network is essentially used to evacuate the hydro power from Bhutan system and surplus hydro power of North Eastern Grid during monsoon. During, non monsoon season with receding hydro the Tala Transmission system experiences high voltage during lean hours. Although adequate reactive compensation has been provided yet resorting to opening of lines are not uncommon during the months of winter. Rest of the 400kV system usually operates within the prescribed voltage limit as specified in the IEGC. 400kV stations at Pusauli or at Jeypore also experience low or high voltages due to the low fault MVA of these stations. As the HVDC stations are also connected to these stations having lower fault MVA, any power flow change associated with switching of filter banks operation render at times wide fluctuations in voltage at 400kV level. 3.2 AVRs of Generators As per the provisions of clause 5,2(j) of IEGC, all generating units shall keep their Automatic Voltage Regulators (AVRs) in operation and power system stabilizers (PSS) in AVRs be appropriately tuned. 3.3 VAR Exchange by constituents for Voltage and Reactive Control In line with clause 4.9(a) of IEGC each constituent shall provide for the supply of its reactive requirements including appropriate reactive reserves, and its share of the reactive requirements to support safe and secure power transfer on interconnecting transmission circuits. The constituent states 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 beneficiaries 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 beneficiaries 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.


3.4 VAR generation / absorption by generating units

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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 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. 3.5 Transformer Taps In line with IEGC clause 6.6.5, 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 400/220kV ICTs as on 1.10.08 is enclosed at AnnexureVIII . ERLDC operator shall maintain this list and incorporate due changes and reasons for change of 400/220kV ICT tap positions. Frequent change of on line tap changing may be avoided to the extent possible . As such 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 for HIGH/LOW voltage VAR drawal pattern at various ISTS interconnection points with states. Effort shall be made to identify such ISTS points where regular VAR payment takes place. Necessary measure shall be initiated to set an optimum ICT taps so as to minimise such VAR payment with pool. 3.6 Control of Voltage at grid substations/generating stations Following corrective measures in order of priority shall be taken by ERLDC and for ISTS system and by SLDC for State systems in the event of voltage going beyond the operating limits as stipulated in IEGC. 3.6.1 High Voltage:

In the event of high voltage following specific steps would be taken by the respective grid substation/generating station at their own, 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 teriary reactors available at ER grid is enclosed at Annexure IX c) Optimization of the filter banks at HVDC terminal d) The Generating units on bar particularly at the proximity of the stations where high

voltage is experienced absorb reactive power within the limit of capability curve. e) Operation of appropriate hydro generators for VAR absorption or as synchronous

condenser wherever such facilities are available f) Checking of possibility of rerouting /change of power flow on HVDC terminals

down power so that loading on parallel EHV network can be altered that may result in reduction in voltage goes up resulting in drop in voltage.

g) Opening of lightly loaded lines around the area /substation where high voltage is reported ensuring security of the balanced network. Due consulatation /advise must be obtained from ERLDC/SLDCs wherever such action would be taken.


3.6.2 Low Voltage Condition

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In the event of low voltage following specific steps would be taken by the respective grid substation/generating station at their own, unless specifically mentioned by ERLDC/SLDCs. However, ERLDC/SLDCs before taking any voltage control action, the reason for low voltage as observed /reported be carefully studied The network adjoining to the substation/s experiencing low 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) Close the lines which were opened to control high voltage after obtaining due

permission from ERLDC/SLDCs. b) The bus reactor be switched out c) The switchable line/tertiary reactor are taken out d) Optimization of the filter banks at HVDC terminal e) All the generating units on bar shall generate reactive power within

capability curve. f) Operate hydro generator for VAR generation g) 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.

3.7 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 such reactors in ER Grid are included in the list of reactors shown at Annexure V 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 Outage Planning

4.1 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 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. 4.2 Objective 4.2.1 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.

4.2.2 To minimise surplus or deficit, if any, in the requirement of power and energy

and help to operate system within system standards.

4.2.3 To optimise the transmission outages of the elements iof 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.

4.3 Scope The scope of this chapter is applicable to all Regional constituents viz.RLDC, SLDCs, SEBs/STUs, ISGSs and CTU ( vide clause 5.7.3 of IEGC). For the purpose of a coordinated maintenance programme, outage programme for the generating stations at Butan viz. Tala HEP, Chukha 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. 4.4 Outage Planning Procedure: 4.4.1 For the purpose of the ( Load Generatyion Balance) LGB/ Outage planning process

OCC( Operation Coordination Committee) of ERPC shall be in general be the forum for reviewing and deciding the outage planning.

4.4.2 It shall be the responsibility of the ERPC secretariat for analyzing the the outage schedule

as , prepare a draft annual outage schedule for finalization of the annual outage plan for the following financial year by 31st January of each year.

4.4.3 All SLDCs/STUs, CTU, ISGS shall provide RPC Secretariat their proposed outage

programmes in writing for the next financial year by 30th November of each year. These shall contain identification of each generating unit/line/ICT, the preferred date for each outage and its duration and where there is flexibility, the earliest start date and latest finishing date.


4.4.4 Each beneficiary shall be responsible to match their demand with the anticipated availability of their own plant and availability from ISGS. The SLDC/STUs along with the proposed outage programme, therefore, shall also furnish details of the anticipated load

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generation balance report(LGBR) to ERPC secretariat in order to facilitate preparation of the annual outage plan

4.4.5 ERPC Secretariat after receiving the outage programme will study the following :-

i) Total power and energy availability( for peak and offpeak 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 other wise

by state beneficiaries 4.4.6 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.

4.4.7 The final outage plan alongwith the Load Generation Balance report(LGBR) shall be

intimated to all Regional constituents and the RLDC for implementation latest by 31st January of each year as mutually decided in ERPC forum.

4.4.8 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.

4.5 Outage planning not covered in Annual Outage plan 4.5.1 Some of the outages not foreseen while finalising annual outage plan will be considered in

monthly OCC meeting of ERPC. 4.5.2 The constituents will furnish outage plan for next month to EREB secretariat by 16th of the

current month. The proposal for planned shutdown of transmission elements will clearly state the details of work to be carried out with flexibility of date and time.

4.5.3 In principle, multiple shutdowns shall not be allowed in the same corridor. 4.5.4 After discussion in the OCC, EREC secretariat will circulate monthly outage plan before 1st

day of the next month to all the SLDCs/STUs/ISGSs / Generating stations of Bhutan and ERLDC along with the preconditions.

4.5.5 A copy of the monthly shutdown programme cleared in the OCC forum shall be kept at

ERLDC control room. 4.5.6 Shutdown cleared in OCC shall be in principle clearance only. Formal Requisition for

shutdown will be given by the constituent involved at least two days in advance and ERLDC, while giving clearance will indicate precautions and actions to be taken.


4.5.7 Each regional constituents/ ISGS shall always obtain final approval from ERLDC prior to availing an outage.

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4.5.8 If any constituent is in need of emergency shutdown, request for the same should be sent to ERLDC along with sufficient valid reasons.

4.5.9 In case of shutdown for HVDC lterminals/ Inter regional lines the proposed programme

preferably be discussed at the regional RPCs s OCC forum and a common date for availing the shut down be arrived at.

4.5.10 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.

4.5.11 Vide clause 4.7(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 iii) Black out in a constituent State iv) Any other event in the system that may have an adverse

impact on the system security by the proposed outage.

4.6 Procedure for Availing the Outage in Real Time 4.6.1 Shutdowns cleared in the OCC shall be in principle clearance only. The concerned

constituent will give formal requisition for shut down at least three days in advance to ERLDC.

4.6.2 RLDC if required shall conduct further system studies based on the system condition and

approve the shutdown at least two day in advance. 4.6.3 Formal requisition for actually availing the shutdown of HVDC terminals/ interregonal lines

may be sent to RLDCs of both the regions atleast five days in advance and clearance for the same shall be issued after mutual agreement by both the RLDCs/NLDC at least two days in advance before actually availing the shutdown.

4.6.4 While issuing clearance of the shutdown ERLDC shall clearly mention the following( vide

format at Annexure X) i) Code of the outage clearence. 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

4.6.5 Such clearances shall be issued to all the constituents affected due to such shutdown.


4.6.6 In case of outage clearance of HVDC links/interregional links, the respective RLDCs, after obtaining due consent from NLDC shall issue clearance messages to all the concerned constituents in their respective regions. Copy of the messages shall also exchanged amongst the RLDCs and other RLDC

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4.6.7 Each constituents/ISGSs shall always obtain a final clearance from ERLDC just prior to availing the outage.


4.6.8 All the codes exchanged during the process for actually availing the shut down shall be logged properly in the logbook maintained by ERLDC. All messages shall be carefully preserved for future references atleast for two months.

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Chapter 5 Periodic Reports and Event Information

5.1 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 Constituents, 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 periodinc reports to be prepared by RLDC to be sent to all constituents of the region and RPC Secretariat 5.2 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 high light performance of the Regional Grid, bring out the system constraints, reasons for not meeting the requirements, if any, of security standards and actions taken. 5.2 Periodic Reports

5.2.1 Weekly Report

As per clause 5.5.1 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 Constituents 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.

The format for weekly report is shown at Annexure XI 5.2.2 Quarterly Reports

A Quarterly report ( vide clause 5.5.2 of IEGC)shall be issued by ERLDC to all Regional constituents detailing the power supply positions during the last quarter, quality of supply, the system constraints being faced an the agencies responsible causing constraints. The format for quarterly report is shown at Annexure XII

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 constituents of any such exceptional requirements and the constituents 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(m) of IEGC , all Regional constituents shall any UFR operation that has taken place in their system and the areas affected with approximate quantum of load relief obtained 5.3 Event Information 5.3.1 Vide clause 5.9.5 any of the following events require reporting by ERLDC/ Regional

constituent.

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 ix) Tripping of any element of the regional grid

5.3.2 Any tripping of an element under the list of important elements of regional grid, whether manual or automatic, shall be intimated by the control centre of the constituent 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 by a constituent which may have an impact on the

regional grid or on any of the important element, shall be reported by the constituent 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 constituent/s shall be reported by ERLDC to such constituent/s in advance.

5.3.5 The intimation and the exact time of revival of any element under the category of important

events will be furnished to WRLDC as early as possible. 5.4 Reporting system The details of event reports and periodic reports to be prepared and issued by constituents / ERLDC are as follows: 5.4.1 In the event of tripping of any element under important elements, the preliminary event

report with possible details shall be sent by the concerned constituent 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 XIII ) shall be sent within the next day.

5.4.2 Such report shall follow the telephonic / flash reporting by the constituent say within a reasonable time say within 10 minutes of the occurrence of the event as stated under para 5.3.2

5.5 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


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5.5.1 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, Sereis 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 at 220kV and above which requires rescheduling of generation or results in frequency drop of more than 0.2 Hz.

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. at 400kV and above which requires rescheduling of generation or results in frequency drop of more than 0.2 Hz

5.5.2 Grid Disturbance Grid disturbance is defined as an incident, resulting in loss of supply in the grid, at the level of 220kV and above Categorisation of Grid Disturbance in increasing order of severity is described as under.

Category 1: When loss of supply of upto 10% of the antecedent generation or load in 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 is lost Category 4: When 30% to less than 40% of the antecedent generation or load is lost Category 5: When 40% or more of the antecedent generation is lost.

ERLDC shall maintain a log ( Vide Annexure XIV) of such incidences/disturbances and whenever such incidences/disturbances occur shall report in writing ( vide Annexure XIII) 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 .

Chapter 6 Network Security and Congestion Management


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6.1 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 grid that may have an adverse effect on ER system. 6.2 Network Security 6.2.1 Background

The Indian power grid has two synchronous grids viz (i) “NEW” Grid comprising of Northern , Eastern, North Eastern and Western region and (ii) the Southern Region grid. With formation of the New Grid, there has been sea change in the operational philosophy in system operation that has already yielded various benefits like peak/offpeak 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 1800-2000MW /Hz. Eastern Region being a availability surplus region is strategically located with synchronised interconnections with all the regions of the NEW Grid besides having synchronous integrated operation with Bhutan Power system. Eastern Grid is also connected to Southern Region through two nos 3000MW capacity HVDC interconnection. The large number of synchronous interconnections with other regions/neighbouring country(Bhutan) with Eastern Region howeverhas 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.

6.2.2 Measures to ensure Network Security and Reliability In order to maintain the security of the Regional power system, it is important that the planned outage of generation and transmission system particularly in the important flow-gates are properly coordinated. The important flow-gates of Eastern region with the limits of flow gates are shown at Annexure XV. 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-XVI. 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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6.2.2.1 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, loopflows 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. Available Transfer Capability (ATC) is a measure of the transfer capability remaining in the physical transmission network for further commercial activity over and above already committed uses. It is derived from the Total Transfer Capability (TTC) after discounting the reliability margins. Thus ATC = TTC - Reliability Margins. This ATC is for scheduling long term as well as short term and collective transactions on the interregional links. In other words the simultaneous net total import or export of a particular region must not exceed the ATC in the respective direction. Reliability margins are also required to take care of the inherent uncertainties in projecting transfer capability over longer time periods. These margins are necessary for reliable transmission services to all transmission system users under a broad range of potential system conditions. Margins in the form of Transmission Reliability Margin (TRM) and Capacity Benefit Margin (CBM) must be kept aside to provide operating flexibility in real time. Transmission Reliability Margin (TRM) Transmission Reliability Margin(TRM) is the amount of transmission transfer capability necessary to provide a reasonable level of assurance that the interconnected transmission network will be secure. TRM accounts for the inherent uncertainty in system conditions and its associated effects on ATC calculations, and the need for operating flexibility to ensure reliable system operation as system conditions change. Capacity Benefit Margin (CBM) Capacity Benefit Margin (CBM ) is defined as that amount of transmission transfer capability reserved byload serving entities to ensure access to generation from interconnected systems to meet generation reliability requirements. CBM would take into account the non-simultaneous and simultaneous overdrawal/ under drawal by the state constituents resulting from demand forecast error or the sudden outage of the largest size generating unit in a control area. In real time


Reliability Margin

Short Term Open Acess and Collective Transactions

Long Term Open Access

ATCTTC

Reliability Margin

Short Term Open Acess and Collective Transactions

Long Term Open Access

ATCTTC

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operation, the TRM and the CBM would actually be used up wholly or partly by utilities in the grid. However, the system operator must always ensure that the system is secure all the time for withstanding the next contingency. 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 constituents will reduce their drawl to the level advised by ERLDC whenever such breach in TTC level among the regions takes place to ensure the grid security irrespective of frequency and schedule . ERLDC would carry out system studies every month to evaluate the Total Transfer capability of inter-regional export/import for the purpose of Short Term Open access Transactions to be approved for the 3rd Month. For the purpose of study ERLDC shall refer to the LGBR ( Load Generation Balance Report) as prepared by ERPC Secretariat. ERLDC shall review the network conditions/congestions and despatch scenarios and may revise declared TTC. In case of any partial outage of ISGS machines the Long Term allocation for utilities gets revised. For the utilities outside the region, such outages would provide margins for day ahead STOA and collective transactions. The 96 blockwise ATC for day ahead transactions shall also be worked out on day ahead basis for transactions through Power Exchange by the utilities. The overall coordination shall be done by NLDC for such transactions 6.2.2.2 Flow gates and Congestion Management Eastern Region being strategically located, it is connected to all the other regions. The typical generation dispatch pattern during monsoon and winter, demand scenarios within the region as well as of the other regions results in congestion in some corridors of the Eastern Network. These congestions are well identified. The anticipated power flow pattern along these flow gates has a direct impact on the Total Transfer Capability in different seasons. While carrying out the system studies for arriving at the TTC and ATC figures anticipated flow pattern along these flow gates need to be checked under and in real time require to be monitored for a secured operation. The various flow gates and their characteristics and actions required to be taken by ERLDC operators during congestions in these flow gates are described below: 6.2.2.2(a) Monsoon Flow gate –I ( allowable limit≈ 2500MW) ( vide Annexure XV(a)) 400kV Purnea-Muzaffarpur D/C ( with TCSC at Purnea) 400kV Farakka – Kahalgaon D/C Scenarios:

• Monsoon ( period Mid July to Sept) • High Availability at Binaguri 400kV S/S (≈ 2000MW and more) due high

generation at the following stations • Teesta = 510 MW • Import from Tala HEP/Chukha HEP ≈ 1100 MW • Import from North Eastern Region ( surplus hydro) ≈400-500MW

• High Demand in Northern Region


During high monsoon the expected import from Bhutan, Teesta and NER are essentially evacuated from Binaguri 400kV S/S. Northern Region having higher demand during these periods most of the hydro power as above is evacuated to Northern Region along Tala Transmission System. The 400kV Purnea – Muzaffarpur D/C because of its lower impedance gets loaded at times beyond 900 MW per ckt. Any outage of one of the ckt of Purnea-Muzaffarpur might therefore lead to a contingency as there would be every likelyhood of tripping of the parallel 400kV Farakka-Kahalgaon D/C ( vide axis of isolation at Annexure XV).

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Congestion Management: In the event of loading across this flow gates exceeding beyond allowable limit( As notified separately during TTC calculation( generally 2500MW or below)) following actions may be initiated : (i) Check whether taking of all the 400kV D/C between Patna-Balia and

Biharsariff – Balia can be taken into service if any of them had been made single ckt to contain overvoltage

(ii) Check whether all 400 kV ckts eminating from Kahalgaon and Biharshariff can be taken into service if any of them had been switched off to contain overvoltage.

(iii) Request NR /NPSD to whether wheeling of power from Vindyachal(WR) to Rihand(NR) is possible or not

(iv) In case ER is availing UI power from SR check whether reduction in UI quantum ease out the congestion or not. Check whether UI transactions to SR over HVDC links is possible or not

(v) Request reduction of thermal generation at West Bengal and DVC system in case they are underdrawing with respect to schedule

(vi) Request curtailment of drawal to NR on account of congestion (vii) Request NR/NPSD to invoke the congestion charge if curtailment of drawal

is not forthcoming. (viii) Verify in case NR has invoked congestion charges on account of

congestion in ER Network, monitor the congestion and inform NR /NPSD immediately as soon as the congestion is removed.

6.2.2.2 (b) Monsoon Flow gate –II ( allowable limit≈ 1500MW or below) ( vide Annexure XV(b))

• 400kV Talcher –Rourkella D/C • 400kV Rengali-Baripada-Kolaghat S/C

Scenarios:

• Monsoon ( period Mid July to Sept) • High Hydro Availability in Orissa. • High Availability in Southern Region and open access • All machines at Talcher Stage II ( 6x500 MW) on bar In the event of high monsoon in Orissa, the surplus availability within Orissa system gets evacuated along the above mentioned flow gate. Although parallel 220kV paths are available, because of lower impedance path and other generation disposition conditions in other utilities as well as in Orissa, the major evacuation of surplus power takes place through Talcher-Rourkella 400kV D/C and 400kV Rengali-Baripada/Kolagat 400kV S/C. The 400kV Talcher–Rourkella D/C gets loaded at times beyond 900MW. Any outage of one of the sections between Rengali- Baripada-Kolaghat or Talcher - Rourkela might therefore lead to a contingency when there is a likelyhood of tripping of the major or all the connectivity between Orissa ( vide the axis of isolation at Annexure XV)system and rest of the New Grid. The capacity addition programme at Korba Complex as well as at around Budipatar complex has also aggravated the problems of congestion during monsoon as mostly power is imported from Westrer Region from Korba complex at Budipatar and wheeled back to Rorkella via Tarkera 220kV D/C.


Congestion Management

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(ii) Request TSTPP/ coordinate with SR for generation reduction if it is

overgenerating with respect to its schedule. (iii) Request Orissa SLDC to explore possibilities of reduction in its hydro

generation( not splling) in order to reduce the congestion. Before issuance of any generation reduction message to Orissa SLDC ensure that Orissa is underdrawing with respect to its schedule

(iv) In case the frequency is low request overdrawing utilities to curtail its overdrawal. Avoid issuance such message to Orissa even if it is overdrawing.

(v) Reduce UI transactions over HVDC links from SR to ER if any . (vi) Coordinate with NPSD/SR/WR to for any UI transaction is possible

via SR-WR HVDC link. If required explore possibilities to wheel UI to WR via SR over HVDC links.

(vii) Avoid issuance of generation reduction message to any other constituents( other than Orissa and TSTPP) within ER even if the frequency is on the higher side.

6.2.2.2 (c) Winter Flow gate –I ( allowable limit≈ 1600 MW or below) (vide Annexure XV(c))

• 400kV Farakka-Malda D/C • 400kV Farakka-Kahalgaon S/C

Scenarios:

• Winter ( period Dec to Mid Feb) • Low Hydro Availability at Bhutan( Tala and Chukha), Teesta, and NE Region • High winter Demand in Northern Region The high demand in Northern Region during winter results in higher drawal from Eastern Grid. As hydro availability in Northe Eastern Region also gets depleted, overdrawal by NE Region is also a frequent phenomenon. The scarce Hydro availability within Bhutan,and Teesta cause thermal power from FSTPP to flow upwards along Farakka-Malda 400kV D/C corridor. Frequent congestion is notice along this corridor as the power in Farakka-Malda 400kV D/C often exceeds 1000MW. Although parallel 400kV Farakka-KahalgaonD/C loading remain within 600-700MW any outage of one ckt between Farakka and Malda might lead to tripping of the parallel corridor also leading to a part isolation of Eastern Grid across the axis as shown in the Annexure XV (c) . Although TCSC at Purnea provides desired stability margin along Tala Transmission system, yet during winter, the TCSC at Purnea may be considered to be kept open as the lower impedance across Purnea-Muzaffarpur section aggravated the congegestion at Farakka – Malda D/C. During 2007 winter the congestion along this corridor could be overcome by keeping the TCSC switched off( vide Annexure XV(c). Therefore, before onset of high winter demand in NR, concerned load despatch centre may review the various corridor loading and consider keeping TCSC at Purnea under switched off condition during winter. Congestion Management


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(i) Check whether taking of all the 400kV D/C between Patna-Balia and Biharsariff – Balia can be taken into service if any of them had been made single ckt to contain overvoltage

(ii) Check whether all 400 kV ckts emanating from Kahalgaon and Biharshariff can be taken into service if any of them had been switched off to contain over voltage.

(iii) Check whether any other corridor connecting ER and NR (iv) Request NR/NER if they are overdrawing with respect to schedule. (v) Check whether any UI transaction over HVDC link to SR is possible

or not. (vi) Request ER constituents to reduce generation if it is under drawing. (vii) Check whether any available hydro generation at Teesta ,Tala or

Chukha can be increased Request (viii) NR/NPSD to invoke the congestion charge if curtailment of drawal is

not forthcoming from NR.

6.2.2.2 (d) Winter Flow gate –II ( allowable limit≈ 1500 MW or below) (vide Annexure XV(d))

• 400kV Jamshedpur-Rourkella D/C • 400kV Kolaghat-Baripada S/C

Scenarios:

• Winter ( Normally Dec to Mid Feb) . • Low Hydro Availability in Orissa/Southern Region • Demand crash in Northern Region due to fog related tripping or due to

inclement weather. During winter months Northern Region experiences sever demand crash due to fog related tripping of its large number of transmission lines. Other than winter months also heavy demand crash in northern region has been experienced due to inclement weather. Sever demand crash in Northern Grid results in wheeling of its surplus availability to Western region. In case of any tripping of Agra(NR)-Gwalior(WR) 400kV section under such circumstances might lead to major instability in the New Grid due to heavy wheeling of power from Northern Grid to Western Grid through Eastern Grid. Any major demand crash evidently would cause system frequency to rise. Such frequency rise essentially provides a commercial signal to the utilities in other regions to avail benefits of economy exchange under UI Mechanism. Immediate increase in drawal within Orissa by reducing its already depleted hydro or over drawal by the utilities of Western region are very common phenomenon under such scenario. While the excess availability within Northern region gets wheeled through ER, the corridor responsible for wheeling of this power( north to south direction) are Kolaghat –Baripada 400kV S/C and Jamshedpur-Rourkella 400kV D/C. These Transmission lines essentially experience congestion under such scenarios. Under such scenarios following other transmission lines may also experience congestion

(i) 400kV Malda-Farakka D/C ( direction Farakka) (ii) 400kV Kahalgaon Maithon D/C( direction Kahalgaon) (iii) 400kV Durgapur –Jamshedpur S/C ( directiojn Jamshedpur)


Congestion Management

ERLDC:POWERGRID

(i) Keep monitoring the voltages at Jamshedpur, Rourkella Jeypore as they are expected to experience low voltage.

(ii) Check/monitor the angular difference between North and West bus of Vindyachal( preferably shall remain within 35-40 degrees) . Keep NPSD informed about ER system status and get updated neighbouring system information from NPSD.

(iii) Request any underdrawing utlities( other than Orissa) to increase its drawal by reduction of generation as per the frequency linked despatch scheme.

(iv) If such low demand condition is expected to continue request NR to consider surrendering of its share from ER ISGSs (other than TSTPP).

(v) Generation reduction at TSTPP and in Orissa may be avoided. (vi) Withdraw /reduce supply of UI from ER to SR. Coordinate with SR for

increase in generation at TSTPP II in case it is under generating with respect to schedule.

(vii) Under extreme exigency request Orissa SLDC to keep more hydro machines( Indravati/Balimela/U-Kolab/Rengali) on bar and advice increase in generation

6.2.2.3 Defence Mechanism Despite the 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 can not 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 Western region to ensure safe and secure grid operation. i) Automatic Under Frequency Load Shedding Scheme. In line with clause 5.2(m) of IEGC, all regional constituents shall provide Automatic Under Frequency and load shedding in their respective system to arrest frequency decline that could result in a collapse / dis-integration 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 constituents shall inform ERPC Secretariat about instances when the desired load relief is not obtained through these relays in real time operation. WRPC 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 XVII 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 preset value when a 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.

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The station is connected to Jaypore 400kv substation of CTU in Eastern Region. Jeypore substation is in turn connected to Indravati (PowerGrid) and Meramundali(OPTCL) thro S/C 400kV lines. However, 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 XVIII 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. For evacuaton of 2000MW of Talcher STPS generation to Southern Region +/- 500kV HVDC bipole transmission system was commissioned for evacuation of 2000MW of power 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 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 and Rengali –Baripada-Kolaghat S/C. During monsoon as such these corridors remain heavily loaded and such contingency of pole block at Talcher 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:


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Both SPS 450 and SPS 1000 schemes are described at Annexure XIX 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 constituentwise/system wise. The islanding schemes as in operation in Eastern Region is shown at Annexure XX 6.2.2.4 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. 6.2.2.5 Operational Areas of Importance The following areas needs careful implementation by the concerned constituents / stations:- i) In case of a 2-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 the two buses at such substation remain connected at leastby 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 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 recluse facility on 400kV lines should always be in service. ERLDC’s approval 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 constituents 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 constituents would also maintain in good operating conditions of all control measures such as defense 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(e), 5.2(f) and 5.2(g) of the IEGC, the generating units should ensure free governor operation.

6.2.2.5 Recording Instruments, Voice and Communication Facilities


i) 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

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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.

ii) Each regional constituent 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.

iii) 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.

iv) 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.

v) For a high degree of service reliability under normal and emergency operation, atleast one main telecommunication channel with an alternate backup channel shall be proviided

6.2.2.6 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 – (Grid frequency ≥ 49.5 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 Actual flow through Flowgate-3 > Limit specified by operator OR Actual flow through Flowgate-4 > Limit specified by operator OR Grid Frequency < 49.5 Hz

EMERGENCY mode – (Resultant output of ALERT mode) AND (Grid Frequency < 49 Hz) Chapter 7

Scheduling and Despatch Procedure


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7.1 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 Chapter 6 and Chapter 7 the IEGC. 7.2 Scope This procedure is applicable to ERLDC and other RLDCs, All the thermal and Hydro ISGSs on which beneficiary constituents have shares and the beneficiary constituents of Eastern Region . For the purpose of seam 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 7.3 Objective This chapter deals with the procedures to be adopted for scheduling of the inter-State generating stations (ISGS) and net drawals of concerned constituents on a daily basis with the modality of the flow of information between the ISGS/RLDCs/beneficiaries of the Region. The procedure for submission of capability declaration by each ISGS and submission of drawal schedule by each beneficiary is intended to enable RLDCs to prepare the dispatch schedule for each ISGS and drawal schedule for each beneficiary. It also provides methodology of issuing real time dispatch/drawal instructions and rescheduling, if required, to ISGS and beneficiaries. 7.4 Description of the procedure The Regional grids shall be operated as loose power pools (with decentralized scheduling and dispatch), in which the States shall have full 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 and any bilateral inter-change shall provide the drawal schedule of each State, and this shall be determined in advance on daily basis. While the States would generally be expected to regulate their generation and/or consumers’ load so as to maintain their actual drawal from the regional grid close to the above schedule, a tight control is not mandated. The States may, at their discretion, deviate from the drawal schedule, as long as such deviations do not cause system parameters to deteriorate beyond permissible limits and/or do not lead to unacceptable line loading. 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

h) Day ahead scheduling i) Revision of schedules j) Implementation of Final schedules

All the relevant formats are enclosed at Annexure XXI


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START

Receive from each ISGS Capacity Availability in Form - A format at 09:00hrs

ISGS Ex-pp Declare Capacity Availability for the following day

Is all applicable DCs Received ?

No

Yes

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.

Is there any change in ISGS DC?

Check and configure the Advance Approved STOAs

Receive STOA Data from OA Dept.

ISGS & STOA (Advance Appd) requisitions of Constituents

Receive requisition from each constituent in Form - C format at 15:00hrs

Are Requisitions of all constituents received?

Cont..2

DC_Rev

Yes

Yes

No

No

% Weekly Loss & Share Allocation %


Name of the Activity: SCHEDULING FOR DAY AHEAD

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From 1

PX Transaction

Wheeling Diversiion Inter Regional Trx

Receive Data from NLDC at 15:00hrs

Preparation of Constituent's Drawal Schedule & ISGS Despatch Schedule

Check for Tr Constraint, Tech Min & Ramping

Req_Rev

Send Drawal Schedule to SLDCs & Despatch Schedule to ISGS -(Form - D) for the following day at 17:00hrs

Is there any change in ISGS DC or Constituent’s Requisition?

Req_Rev

Check / configure the Day Ahead Approved STOAs

Receive Data from Grid Mgmt

DC_Rev


Send final Drawal Schedule to SLDCs & Despatch Schedule to ISGS -(Form - D) for the following day at 23:00hrs

Is there any URS

Not OK OK

Yes

No

No

Requisition Change

DC Change

Is there any URS Power?

END


Broadcast the URS Details to All the Constituents & Upload to RLDC Website

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Activity: REVISION OF CURRENT DAY SCHEDULE

START

Receive the revised of ISGS Capacity Availability in Form - A format

Is it due to forced

outage of Unit?

Prepare ISGS Entitlement of all constituents in 15min time blocks w.e.f 4th time block - Form - B

Send From - B to all the beneficiary constituents



Send Drawal Schedule to SLDCs & Despatch Schedule to ISGS.

(Form - D)& upload to web


Broadcast the URS Details to All the Constituents and Upload to RLDC website

Is there any Change in DC of

ISGS?

NoRR

Receive Revised Declaration of

Available Capacity of ISGS

Prepare ISGS Entitlement of all constituents in 15min time blocks w.e.f 6th time block - Form - B

Receive Revised Requisition from the Beneficiary Constituents

Send From - B to all the beneficiary constituents

Receive requisition from constituent in Form - C format

Yes

No Yes

OK

Yes

END


Not OK

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Activity: Procedure flow chart for current day schedule revision…contd

RR

Receive the revised Requisition of the

Beneficiary Constituent in Form - C format

Is SLDC Changed its Requisition?

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


Send Drawal Schedule to SLDCs & Despatch Schedule to ISGS -(Form - D)


END

Preparation of Constituent's Drawal Schedule & ISGS Despatch Schedule w.e.f 4th time block


Broadcast the URS Details to All the constituents & Upload to RLDC website

Yes

Yes Yes

Is it NEW Approval of Same Day STOA?

Yes

NoYes Is there any System Constraint?

No

END

No

No No

Yes


No

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Activity: IMPLEMENTED SCHEDULE

START

Yes

No

Regional Weekly Loss % State System Loss %

Are Loss % Values entered correctly?

Correct the values as applicable for the particular day

NoCorrect the values as applicable for the particular day

Are Loss % Values entered correctly?

STOA Details (Advance Approved & Day Ahead Approvals)

Are STOAs Configured correctly?

Correct the values as applicable for the particular day

No

Details of Grid Incidents and Grid Disturbance if

any.

Yes

Was the Schedule Revision done

correctly?

Yes

No

Details of Revisions in Declared Capacity of

ISGS & Requirements of Constituents

Check for the Constituent's Drawal Schedule & ISGS Despatch Schedule & co-ordinate for rectification of errors if any.

Yes

No

Cont..2

Share Allocation %

Yes

Correct the values as per Declaration in line to IEGC provisions

No

Details of Transmission Constraints, if any.

Was the curtailment done

correctly?

Incorporate the curtailment with correct values as per IEGC guidelines / provisions

Was all the Revisions scheduled correctly?


Yes

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From 1

Inter Regional Link Schedules Check for matching of the Inter Regional

Schedules for each link. (STOA & Wheeling / Diversion Details)

Co-ordinate with respective RLDCs & eliminate the discrepancy.

NoAre the Inter Regional Link Schedules are matching with other

Region?

Communicate to respective RLDC

Yes

Release the Final Implemented Schedule and Upload in to Web.

Is there any dispute on

discrepancy of the Schedule, with in 5 days?

Receive from SLDC / ISGS / Traders / RLDCs

Go to Start

Yes

No

END


Release weekly schedules to commercial dept for Energy Accounting

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CHAPTER 8

SCADA SYSTEM OPERATION

8.1 SCADA / EMS System Operation This manual prepared for the use of them who intend to operate the SCADA / EMS system installed at ERLDC to help them with real time information pertaining to ER power system grid and to facilitate system study with information available from the real time system. 8.2 System Configuration This section gives only a brief description of the hardware. The intend is to have an idea about the type of hardware components available not the quantity and the detailed technical specifications. The RSCC system hardware architecture is represented below :

RSCC Hardware Architecture

The equipment Ids are marked as blue in the above mentioned diagram. The details of networking equipments and printers / loggers are not included. 8.3 Starting up an operator console Before starting a operator console check the availability of power to the monitor and the server machine. On switching on the power supply, the machine will start up and the login prompt shall be displayed for operator login :

SCADA/EMS Servers

(EA0DS1 & EA0DS2)

ISR Servers

(EA0HS1 & EA0HS2)

ICCP Servers

(EA0IC1 & EA0IC2)

DTS Server

( EA0DS3 )

Communication Front-end (EA0FE1 &

EA0FE2)

Operation Scheduling Consoles (EA0CO1 &

EA0CO2)

Network Managemnt

Console ( EA0CN1 )

Development Console

( EA0PC1 )

Operator Consoles

( EA0OC[1 - 9] )

WAN Peripheral Routers Equipment

( EA0VP1 )

To SLDCs To CPCC

Remote VDUs To RTUs


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Username for operator console : supervis Password : supervis

ilable to the user for interacting with the SCADA/EMS system :


The following display shall be ava

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8.4 Identifying the failed node The status of the equipment connected in the network is available on the following display. The colour of a the healthy node is green. The colour code used for the display is given below : Green : Available Red : unavailable / out of date Brown : Ready for recovery


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There are ten different displays are available for showing the status of all the nodes available on the SCADA LAN. To call the displays from EMS panel, follow the following navigation path : Click on “SYSTEM MGMT “ button to call up “System Management Display” Click on “Displays” button against “COMPUTER STATE AND CONTROL” Click on “SITE OVERVIEW : DATA SERVERS” BUTTON


The status of Data Server nodes shall be available.

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For other displays : from related display pull down menu call up the displays. 8.5 Calling up a substation displays Individual substation displays are available for all the stations for which telemetry is available. The displays are arranged control center-wise which may be called up using pull down menu as follows: Navigate => Master Menu : to call up system displays menu


Click on “ONLINE” button to call up E SC&C ONE-LINE displays

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The corresponding displays are available on the respective “Displays” button. 8.6 Bringing-up Video Projection Display (VPS) The VPS is driven by a P-III window based machine connected to on-line network. This is machine is communicating to the dataservers through “Exceed” software. A station for VPS has been configured on both the data servers which is called through a “PC-Rapport” program.


A desktop icon “PCRAPPORT.BAT” is available on the desktop of the VPS machine. On double clicking on this icon, VPS station will be started with the pre-defined room. Subsequently, the required rooms may be called from the PC-Rapport menu

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It may be mentioned here that the trending displays cannot be saved as a room and the trend displays are to be called up separately through separate desktop icon “trend_ea0ds2” 8.7 Configuring data Trends Any analog value ( telemetered or calculated ) can be plotted against time in real time to see the trend of the selected value. To call up a trend display go to session manager Go to pull down menu ER SC&C tab and select Start prograf. The trend display shall be started with the default trend. To add particular point on the trend display, first select the point and then click on the value. A pop-window shall be available. Select trend & display and then done button. The point shall be added to the trend. Then to configure the trend navigate Master menu => SCADA =>Trend => Point Assignment Then in the point assignment window, Select Track / Add New Track and assign point from available point list. The scale, zoom, history can be configured from the PM pull down memu. NOTE : In case the value is available in the available point list, the same point should not be added additionally to save buffer space.


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8.8 Manually Defining of Data ( Replace / Not in service ) The following sections describe procedures that relate to modifying data values for analogs and status points. If a modified value is rejected after completing any of the procedures in this section, it may be for one of the following reasons:

• The value might need to be put in the “not in service” state. • The value is normally supplied by the State Estimator. • You attempted to enter a null value. • You entered a value outside of the reasonability limits.

8.8.1 Manually Overriding Point Values From a Oneline

This procedure is used to remove a point from service and enter an operator override:

a. On a Oneline, select the device symbol.

A popup box appears. b. Select the Remove button.

The "not in service" symbol appears next to the button.

c. Select the Select button, and the toggle button on the popup becomes available for use.

d. Select the toggle button.

If the device status is currently OPEN it changes to CLOSED; if the device status is currently CLOSED it changes to OPEN.

e. Select the Done button. The popup disappears. Note that the manually replaced symbol appears next to the device on the Oneline, indicating that the status has been manually overridden.

8.8.2 Manually Overriding Analog and Count Values From a Oneline This procedure is used to remove an analog or count from service and override its value.

a. On the Oneline, select the analog field.

A popup box appears.

b. Select the Remove button.

The field containing the analog value becomes enterable.

c. Position the cursor on the field containing the value, type in the new value and press the Enter key.

The entry is accepted if you have permission for entry and the value is within the reasonability limits. If not, the entry is rejected.

d. Select the Done button.

The popup disappears. Note that the analog's value has changed on the Oneline, and that it is accompanied by a “manually replaced” symbol.

8.8.3 Removing Manual Override and Restoring a Value to Service


As the previous sections indicate, when a value is manually overridden, both the "manually replaced" and "not in service" flags are set for the point, analog, or count involved. The following procedure removes both flags from the point, analog, or count, and causes its value

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to be replaced with the next scanned value. If the point, analog or count has simply been removed from service without having its value manually overridden, the following procedure simply returns it to service.

a. On the Substation Tabular display, select the point, analog, or count's depressed Not In Service button.

The point, analog, or count is restored to scan. On the tabular display, the point, analog, or count's Data Quality field no longer reads Replaced, and its "not in service" flag is removed (as can be seen by selecting the Flags button).

8.9 Data Quality flags

Composite data quality flags flags indicate a measurement's reliability. However, composite flags provide a quicker way for the operator to judge reliability which are available on the display along with real time value. There are four composite flags⎯GOOD, REPLACED, SUSPECT, and GARBAGE⎯which are defined below.

• GARBAGE: Data is unreliable. This flag appears when the measurement point is uninitialized.

• SUSPECT: Data is labeled with one or more of these flags: OLD, BAD, OVER, REMSUSP, and QUEST.

• REPLACED: Data is labeled with MANREP, ESTREP, or REMREPL

• GOOD: Data is not labeled as GARBAGE, SUSPECT, or REPLACED.

8.10 Collection and Viewing the Disturbance Data The data available in SCADA is stored in a file called HDR file. These files can be used for viewing the data and playback. The following steps are to be followed to reconstruct the database as it existed during a particular date and time, and to follow it through subsequent scans.


1. Call up the Historical Data Recording display and select the HDR Reconstruction Control display from the Related Displays menu.

Navigate => SCADA => HDR Reconstruction Control

The HDR Reconstruction Control display appears.

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2. Select the Start button.

The Reconstruction function is started and the Reconstruction File Directory is created. This directory lists the HDR historical files from which data can be reconstructed.

a. In the box underneath Reconstruct To Time, type the date and time for which you want SCADAMOM to be reconstructed, then press Enter.

b. Select the Reconstruct To Time button.

HDR takes data out of the historical files and reconstructs SCADAMOM as it existed during the desired time.

8.10.1 Playing Back a Reconstructed Database HDR has a "playback" feature that enables to follow the progress of a reconstructed database over time. The number of seconds between database reconstructions, and the time interval between advances in the playback need to be specified.

To "play back" a reconstructed database, do the following:

a. Reconstruct the database to a given date and time (see steps 1-4 under Error! Reference source not found.).

b. In the RATE field on the HDR Reconstruction Control display, type the number of seconds between database reconstructions, then press Enter.

c. In the Every field, type the number of seconds between advances to the next database reconstruction, then press Enter.

d. Select the Playback button.

Automatic playback begins, based on the time values entered.


e. If you want to pause the playback, select the Pause button.

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The current database reconstruction remains in place, without advancing to the next one.

f. To resume the playback, select Playback again.

Playback resumes, advancing to the next reconstruction at the prescribed interval.

g. When finished, select the Exit button.

HDR exits the reconstruction function.

Note: Once Playback is completed, select the Reconstruct To Time button to start another Playback.

8.10.2 Viewing SOE data To view the SOE data dump of the previous days follow the following steps Go to session manager Go to pull down menu => ER SC&C

Select the start SOE dump viewer, the program will ask for the host computer name. Enter : EA0OC2 ( The program shall run on EA0OC2 ) A notepad editor will open along with a file open pop-up window.

8.10.3.1 PICTURE Navigate to select the date and the file from ( DK0:[pan25.bp.data] ) Double click on BP folder ( LEFT pane ) Select DATA folder ( LEFT pane ) Select the file by scrolling ( from the right pane ) Double click on the selected file, the file is available on the notepad. 8.10.3.2 Transferring SOE data to a PC ( EA0CO1 )

Double click on “get SOE” shortcut icon available on Desktop. Select the SOE file to be copied to pc. Observe the directory selected on PC for transferring the file Select the SOE file and drag the same to the PC. Close the copy application Open the file using notepad / Excel from the directory.

8.10.4 Alarms and Notepad

SCADA detects and notifies operators of events and conditions in the monitored system that can lead to operational problems. For example, SCADA can detect when a normally closed circuit breaker trips, and can take action. SCADA can detect problems that occur for status, analog, and count points, RTUs and other equipment in the communications system, and intersite communications equipment and software. Individual analog or status points may optionally be configured to suppress the alarm until the analog or status has remained in the abnormal state for a specified period of time. In addition, SCADA can detect when control operations fail.

Some of the common conditions and events that SCADA considers abnormal, and therefore alarmable, are as follows:


• Abnormal and illegal conditions for analog, status, and count points in the monitored system.

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• An analog or status point's return to normal operation after being in an abnormal or illegal state.

• Problems in the communications system, in particular with RTUs and scan groups.

These alarms are logged separately and can be viewed based on requirement. To view the current list of analog and status alarms go to EMS panel and click on “EXCEPTIONS” button.

The time ordered alarms will be listed.


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8.11 Area of Responsibility (AOR)

In the SCADA database the entire system (including all of the SCADA control sites) is divided into areas and each area is named. Each area is referred to as an area of responsibility. Dividing the control system into areas serves two purposes:

• It restricts the control of monitored devices to specific control sites and to individual operator consoles within each site.

• It limits which control sites, and which operator consoles within each site, can respond to alarmed conditions and events.

An area of responsibility is assigned to each device type in the monitored system and to each RTU in the communications system. For a control operation (such as remove/restore) to be carried out from a control site and operator console, the area of responsibility of the device type or RTU must match the area of responsibility of the operator's console.

Similarly, an area of responsibility is assigned to RTUs, SCADA sites participating in intersite data transfer, and substation voltage for the purpose of limiting which operator console can respond to alarms.

Again, the console's area of responsibility must match the area name of the alarmed RTU, remote site, or substation, in order for the alarm to be heard or seen at the console.

8.12 Saving Layout and Restoring The user can choose to save desired set displays in a work station for his convenience of use. 8.12.1 Arranging a layout

Open the desired displays and arrange them properly. This becomes a layout.


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8.12.2 Saving a Layout Open RFG station Manager.

Then type the following command in the command window room /save <name> New room will be saved with the layout selected. The same will be available in the room directory for calling up the display. 8.13 Procedure to run Real Time Network Analysis (RTNET) and Study Mode Network

Analysis (STNET) Login in any operator console under supervise mode. Click on Navigate -> Master Menu->Net _Security -> On-Line Network sequence-> Network Online Sequence. In the opened display click on Run Sequence button. Wait for the sequence to complete and check the program status. It must be either VALID SOLUTION or SOLVED WITH EXCESS MISMATCH or INVALID SOLUTION


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If the solution state is Invalid -> In order to identify on which last Bus the program unable to converge -> go to Real time Network solution sequence display (From Network Online sequence-> Related displays->selecting Real time Network Solution Analysis).


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In this display See on which last bus it was unable to converge (At Bus xxx) -> now click on Related displays-> Network Components -> Network Bus summary -> Select Bus Symbolic View-

>


Enter the Bus Number xxx in the field besides to Position to Bus -> Now click on the button Position to Bus-> You will be placed at that particular Bus No:xxx->

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On the Bus symbolic view, for each device you have two flows are showing for MW and MVAR. The bottom value is SCADA Value and the Top value is estimated value. Now compare this SCADA and Estimated values, locate the problem rectify it accordingly either by enabling that measurement ( For this go to Telemetered Network data display (on the Network online sequence display-> click on Related Displays-> select Telemetered Network Data-> click on All Analog Measurements View->Click on Directory Button->

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Select the particular station which was unable to converge.->enable the particular measurement from this telemetered Network data display. Some times scada value might have wrong in that case rectify the scada value by replacing both MW and MVAR of particular device and enable this value in the telemetered network display may help to resolve the problem. Run the sequence again from the Network Online sequence display. See if the solution converges or not. If not remove that particular device (temporarily) from the network and run the sequence .

Note : some times you have to reset the errors which have been accumulated in the Network applications by going to Network Online Sequence main display -> click on the button SE Initial Conditions -> SE Controls View - > Select the buttons COLD INIT, FLAT START, Iteration Type to REFACTOR, reset Standard Deviation (STDEV)and Bias. By doing this you are making the algorithm to initialize. This will help to improve your Network convergence.


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If the solution state is Solved with excess mismatch: We have to identify on which Bus the exdess mismatch has come. Not that here the mismatch we are talking is the algebraic sum of estimated values on the given Bus. go to Real time Network solution sequence display (From Network Online sequence-> Related displays->selecting Real time Network Solution Analysis). In this display select the view Bus Mismatch -> see the Buses which are having highest MW and MVAR Mismatch. Note down the Bus number -> now click on Related displays-> Network Components -> Network Bus summary -> Select Bus Symbolic View->Enter the Bus Number xxx in the field besides to Position to Bus -> Now click on the button Position to Bus-> You will be placed at that particular Bus No:xxx->Locate on which device the excess estimation is happening by comparing with SCADA and rectify it accordingly as explained above.

Once your state estimator getting VALID solution, increase your network by enabling more and more SCADA data in to RTNET. Converge the solution. Check on the One-Line display for all the Central station and then for other constituents how SCADA and estimator values are matching. Rectify the problems if found as explained in the above.


Running Powerflow/Load flow with Realtime Snap-shot:

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Once your network started converging and giving the good quality solution, with SCADA and Estimator values are matching in more and more places you can run the Powerflow program on STUDY mode. For this login in Engineer mode in any of the operator console go to NET_STUDY-> NETWORK STUDY button-> NETWORK STUDY display.

On this display click on the DATA RETRIEVAL button-> In the opened window, click on Copy Real time Application Data -> Done. This will copy the RTNET database of Last run in to study clone.

Wait for 5 minutes to copy the Real time data in to study family and once you get the message in the Solution state: Completed Database copy, you click on Input Setup button.


In the opened window two buttons are present. One is Update Network Topology and the other one is Evaluate Time Depend Data. Click on both the buttons, one by one. Now click on the Run Solution Sequence button and see whether the POWERFLOW program is converged or not by checking the field PROCESS STATUS:. If the solution converges it shows the status as UN LOSS DONE. In case of Non convergence it will show as either INVALID solution or Max Iteration or case Diverged. In that case you go to the display POWERFLOW SOLUTION ITERATION from the Network STUDY display -> Related Displays-> Powerflow displays -> Powerflow Study -> Now again click on Related displays from this display -> click on Powerflow

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Solution Iteration. On this display you can find what are the substations having error values giving problem to Powerflow program. To rectify this you have to again tune your RTNET application for these problematic substations and then you run POWERFLOW as explained above.

Please note that Converging Powerflow will come with experience.

Running Powerflow and comparing the Results: Some times you need to analyze what will happen if you take a Bus shutdown or a Line trip and also the possible effects on the other lines. To do this in Powerflow program we have total 3 study clones are provided.we can copy the Real –time data from RTNET in to these clones and run the powerflow with and with out the disturbance. Then we can compare the results.

That is first we will work in Study1 clone -> Run the Powerflow as explained in the above section. Now click on the Compare Results and other Studies button -> In the opened window-> click on Go To Study2 Button-> It will give the message “Areas have been assigned correctly .In this clone also you copy the Basecase from RTNET. Now create some disturbance like tripping a Generator or removing line etc by Related Displays ->Network Components -> Network Bus summary. Go to that particular Bus , Then remove the component.

Next come to the Main Network Study display by clicking Study Button. Click on Input setup-> Update the Network Topology. Now run the Power flow program by clicking on Run solution sequence. After solution converges, click on the button Compare Results & Other Studies button ->Click on the button Compare with Study1 button. Wait for comparing to finish Next you can see the results by clicking on Comparison Results. Select various views such as Line ,Gen etc and see how the effect of removing this component.


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8.14 Transfer of Schedules to SCADA System Daily schedules are being prepared in Excel platform. One sheet, “online” has been prepared to copy the data to SCADA system, An macro on VB has been prepared, which copies the data to a realtime machine “EA0CO2” as when the schedule is revised. The operator has to be click on the button “schedule upload” button made on Excel after the schedule is revised. A separate macro on VB has been prepared which updates the data in the respective cell of the file “current schedule.xls” in each 15 mins and the data of the respective cells are pumped back to SCADA server through “HABCONNECT” utility. 8.15 Realtime data availability from other region The following text file containing real time data of the other regions are sent through ftp protocol in each 1 minute interval to one of our machine “LOADCURVE”. The files are kept in the folder c:\usr\viswanadh \region

1. NR.txt 2. SR.txt 3. NER.txt 4. WR.txt

One macro on VB project which is running of “EA0CO2” in “external update.xls” file which is opening the above files sequentially and prepares the data for pumping back to SCADA through “HABCONNECT” utility. 8.16 Data transfer to NPSD The real time data is being sent to NPSD in a text file through ftp protocol. The remote system is collecting the data logging in to our machine “LOADCURVE”. The file is being transferred is erdisplay1.txt. The location of the file is c:\online. The file is getting updated in one minute interval through a macro on VB available in MOPdata.xls through “HABCONNECT” utility. 8.17 Uploading Daily Report on ERLDC Website The real time data has been made available to ERLDC website utilizing the same text file being sent to NPSD. The text file is also transferred to ERLDC web server and aspx page has been developed to display the data fro the text file. The file is transferred to web server through ftp protocol. 8.18 Data communication with NLDC for PX scheduling The data communication with NLDC in respect of PX transactions is being done through a dedicated network with NRLDC. The text files are exchanged through ftp protocol for sending the ATC to SLDC and schedule implementation. 8.18.1 ATC Declaration : By 09:00 Hrs. ATC for STOA for the following day

= TTC – RM – LTOA ( following day ) – STOA ( advanced )


To achieve the STOA quantum the following configurations have been made.

ERLDC:POWERGRID

One <calculation file.xls> ( Location : C:\ px_files on shift in charges machine ) has been prepared in which the above calculations are done. The entries of the above file is taken through a program from <Form- D> sheet & <Share table> sheet of the same file for LTOA transaction and <OPEN ACCESS MMMYY> file for advance STOA transaction. The file is being updated by Open access group. The following checks are carried out before sending the ATC file to NLDC.

1. Share table in calculation.xls file as when it is revised for the schedule file 2. LTOA transactions ( excl. ISGS ) in the <Form – D> sheet. 3. DC to be revised in case of confirmed outage on the following day. 4. TTC and ATC figures in all the regional sheets ( available in the <calculation file.xls >

file to be changed in case of contingency. Normally this is being taken care off by Open access group based on TTC / ATC declared on monthly basis.

5. Percentage loss on the calculation sheet should also be checked on Sunday ( as the loss % age is changed on Monday). Normally this is being taken care off through a program. However for confirmation this may be checked after sending the file.

Information sent for ATC is being stored as 00ERATC<mmddyy>.xls under c:\px_files\daily files. The file is sent to NLDC server ( IP :192.168.55.74 ) through ftp. 8.18.2 Receipt of PX transaction from NLDC after 16:00 Hrs NLDC shall finalise the PX transaction by 16:00 hrs and the shall be made available at the NLDC server which needs to be download to the schedule machine for incorporation in the daily schedule of ERLDC. A program has been prepared <PX DOWN>for downloading the file on excel. The file ( .csv format ) shall be downloaded at c:\px_files\px_data. The name of the files are

1. <01ERIEXddmmyy.csv> for IEX 2. <01ERPXIddmmyy.csv> for PXI

8.18.3 Incorporation in the schedule The required transaction ( Utility code given ) available row wise ( 96 block ) to be incorporated in the schedule file <PX> sheet of the relevant schedule file. ( A program shall be made available ) 8.18.4 Confirmation of the schedule to NLDC to be done by 18:00 Hrs A file is to be sent to NLDC server after incorporation of the PX transaction. A program has been prepared <PX UPLOAD> which shall send the file to NLDC server. The program at the same time changes the ATC file available in the shift in-charge machine for releasing the day ahead and contingency transactions. The application received for day ahead/contingency to be approved / consented based on the available ATC. 8.18.5 Uploading of schedules to the web by 18:00 Hrs The daily schedules ( rev – 0 ) after incorporating the LTOA, advanced bilateral transactions and PX transaction is to be uploaded to the web through <SCHD UPLOAD> button available on excel in Schedule machine. 8.19 Daily report upload


The daily reports are prepared on .xls format. The same is converted to .pdf file <ddmmyy.pdf>. The same is uploaded along with frequency plot to the web through ftp protocol.

ERLDC:POWERGRID

8.20 Operation of DG Set in Auto/Manual Mode ERLDC is having two DG sets, 400 KVA and 125 KVA. The higher capacity unit caters all the load like ac plant, lift including ERPC load, the smaller unit caters only the load of technical block of ERLDC. The old unit i.e. 400 KVA unit does not have automatic start facility however auto start facility has been provided with the smaller unit. 8.20.1 Starting sequence of 400 KVA unit In case of main supply failure, the toggle switch is kept to “ENGINE” side. The start button of S.D. valve is pressed for a duration of 30 secs. Subsequently, the self start button is pressed to start the engine. The voltage builds up and frequency meter starts showing the frequency of the generator power. “RAISE” and “LOWER” button is used to bring the frequency to near 51 Hz. Then the outgoing switch is switched to extend supply to the main switch gear panel. The capacitor bank should be switched off before starting the DG set. In the main switchgear panel, incoming switch of the main supply ( CESC ) is switched off and the incoming switch of the 400KVA (marked as F)is switched on to extend power supply to the common bus.


VOLT

KWH

FREQ AMP

START (SELF)

START ( S. D. Valve )

ON

ENGIN

RAISE LOWER

ERLDC:POWERGRID

8.20.2 Operation of 125 KVA set The machines are generally kept on manual mode (1) as most of the time 400 KVA set is in operation in case of main supply failure. To start the engine, the start button is pressed. The engine starts and the supply is extended to the ac panel technical block. Control panel of new DG Set ( 125 KVA ) The following indicator displays are available for operators checking :

1. DG Supply on 2. DG load on 3. Battery Charger on 4. Low fuel level

Toggle switches have been provided to make battery charger on / off and to reset hooter. Further operator buttons have been provided for tripping and closing the alternator and fault reset ( relays )


DG SUPPLY ON

DG LOAD ON BAT CHARGER ON

LOW FUEL LEVEL

HOOTERON

OFF

ON

OFF

BAT CHARGER

ENGINE START

ENGINE STOP

ALT CONN. CLOSE

ALT. CONN TRIP

FAULT RESET

1

3

2

1

3

2

1. MANUAL 2. AUTO 3. TEST

1.TICKLE 2. BOOST

1

2

ERLDC:POWERGRID

Chapter 10 Metering and Settlement System

11.1 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 by the constituents. This chapter indicates the roles and responsibilities of the different constituents in making the settlement system operative in most efficient manner. 11.2 Metering and Data Collection 11.2.1 As per Chapter-6 clause 6.4.14 of IEGC, the CTU shall install Special Energy Meters on

all inter connections between the regional constituents 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.

11.2.2 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.

11.2.3 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 WRLDC in time.

11.2.4 All concerned entities having SEMs shall also carry out necessary time adjustments in the meter as per the procedure already in vogue/advice of

11.2.5 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.

11.3 Data Processing 11.3.1 As mentioned in section 10.2.3, all the energy meter data would reach ERLDC by every

Monday via email. The CTU/STU, ISGSs and Constituent beneficiaries 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.

11.3.2 The computation of the net injection of each ISGS and actual net drawl of each beneficiary shall be carried out in line with clause 6.4.15 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.

11.3.3 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 ERPC Secretariat.

11.3.4 The final schedule implemented by ERLDC shall be open to all constituents for checking / verification for a period of five days and mistakes/omissions ,if any ,would be rectified.

11.4 Energy Accounting 11.3.1 ERPC Secretariat would process the information provided by ERLDC and other utilities to determine the following energy accounts: 11.4.1 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

ERLDC:POWERGRID

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.

11.4.2 Weekly UI( Unscheduled Interchange) Account ` Weekly UI charges shall be settled as per UI calculation for each 15 minute block. The UI

charges payable/receivable shall be calculated with respect to UI Pool. The Pool Account shall be maintained by ERLDC . The UI account as prepared by ERPC Secretariat shall have the following components a) UI charges payable by beneficiaries/ISGSs to Pool b) UI charges receivable by the beneficiaries/ISGSs from the pool c) Pool balance amount due to capping of UI rate for Thermal ISGSs. Since the hydro stations within Bhutan System is not covered under UI mechanism of settlement, 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.

11.4.3 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 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.

11.5 Pool Account Operation In line with Annexure-I of IEGC, from the date of issue of weekly UI and Reactive Energy Charge Account by ERPC Secretariat, within 10-days, the concerned constituent shall pay on priority the indicated amount into regional UI and Reactive Energy pool accounts operated by ERLDC. The agencies that have to receive the money from pool accounts would then be paid within 3-working days. These pool accounts are to be reconciled once in periodic intervals.


ERLDC:POWERGRID

Annexure: I Generation capacities in Eastern Region

(AS ON 31.10.2008)

INSTALLED CAPACITY EFFECTIVE CAPACITY

CONST. THERMAL HYDEL GT TOTAL THERMAL HYDEL GT TOTAL

BSEB 554 45 0 598 536 45 0 581

JSEB 840 130 0 970 770 130 0 900

TVNL 420 0 0 420 420 0 0 420

DVC 3100 144 90 3334 3070 144 90 3304

TTPS(NTPC) 470 0 0 470 460 0 0 460

OHPC 0 2069 0 2069 0 2069 0 2069

OPGC 420 0 0 420 420 0 0 420

WBSEDCL 0 1064 100 1164 0 1064 100 1164

WBPDCL 3970 0 0 3970 3880 0 0 3880

CESC 1035 0 0 1035 975 0 0 975

DPL 695 0 0 695 690 0 0 690

* SIKKIM 5 33 0 38 5 * 33 0 38

NTPC 4440 0 0 4440 4440 0 0 4440

NHPC 0 570 0 570 0 570 0 570

REGION 15949 4054 190 20193 15666 4054 190 19910

CHPC 0 336 0 336 0 336 0 336

KHPC 0 60 0 60 0 60 0 60

TALA 0 1020 0 1020 0 1020 0 1020TSTPP stg-II NTPC ** 2000 2000 2000 2000Total 17949 5470 190 23609 17666 5470 190 23326** TSTPP stg-II (2000MW Capacity) is situated in ER supplying power only to SR. constituents & GRIDCO (Orissa) has a share of 200MW* Includes 5 MW Diesel set in SIKKIM

INSTALLED & EFFECTIVE CAPACITY


ERLDC:POWERGRID

Annexure :II List of Generating Units and their Capacities ( As on 31.10.08)

ALL FIGURES IN MWSTATION INS CAP EFF CAP

UNITS TOTAL UNITS TOTALTHERMAL BARAUNI 2x50+2x110 320 2x50+2x105 310

MUZAFFARPUR 2x110 220 2x110 220PATNA 2x1.5+1x3+ 13.5 2x1+1x4 6

1x7.5TOTAL 553.5 536HYDRO KOSI 4x5 20 4x5 20

DEHRI ( BHPC ) 7x1.65 11.6 7x1.65 11.6OTHERS 13.3 13.3 13.3 13.3

TOTAL HYDRO 44.9 44.9GRAND TOTAL THERMAL+HYDRO 598.4 580.9

STATION INS CAP EFF CAPUNITS TOTAL UNITS TOTAL

THERMAL PATRATU 4x50+2x100+ 840 4x40+2x90+ 7704x110 2x105+2x110

TOTAL 840 770HYDRO SUBERNREKHA 2x65 130 2x65 130TOTAL HYDRO 130 130TVNL TENUGHAT 2x210 420 2x210 420GRAND TOTAL THERMAL+HYDRO 1390 1320


THERMAL BOKARO'B' 3x210 630 3x210 630

DURGAPUR 1x140+1x210 350 1x140+1x210 350

CHANDRAPURA 3x140+3x120 780 3x130+3x120 750

MEZIA 4X210 +2x250 1340 4X210 +1x250 1340TOTAL 3100 3070

GAS TURBINE MAITHON 3x30 90 3x30 90

MAITHON 3X20 60 3x20 60HYDRO PANCHET 2x40 80 2x40 80

TILAYA 2x2 4 2x2 4TOTAL 144 144GRAND TOTAL TH+ HY + GT 3334 3304Note:-Bokaro 'A' of DVC has been decommissioned w.e.f. 22.12.2006

D V C SYSTEM

BSEB SYSTEM

JSEB SYSTEM


ERLDC:POWERGRID

ALL FIGURES IN MWSTATION INS CAP EFF CAP

UNITS TOTAL UNITS TOTALTALCHER (NTPC)

THERMAL STAGE-I 4x62.5 250 4x60 240STAGE-II* 2x110 220 2x110 220

TOTAL 470 460

HYDRO(OHPC) BURLA 2x49.5+3x37.5 259.5 2x49.5+3x37.5 259.5+2x24 +2x24

CHIPLIMA 3x24 72 3x24 72BALIMELA 2X75+6x60 510 2X75+6x60 510RENGALI 5x50 250 5x50 250U.KOLAB 4x80 320 4x80 320U.INDRAVATI 4x150 600 4x150 600MACHKUND 57 57

TOTAL HYDRO 2068.5 2068.5

OPGC IB VALLEY 2x210 420 2x210 420GRAND TOTAL THERMAL+HYDRO 2958.5 2948.5


THERMALBANDEL 4x82.5+1x210 540 4x60+1x210 450SANTALDIH 1X250+4x120 730 1X250+4x120 730

WBPDCL KOLAGHAT 6x210 1260 6x210 1260BAKRESWAR 4x210 840 4x210 840SAGARDIGHI 2 x 300 600 2 x300 600

DPL DPPS 2x30+3x75+ 695 2x30+1x70+ 6901x110+1X300 2x75+1x110+1X300

TOTAL 4665 4570

JALDHAKA-I 3x9 27 3x9 27JALDHAKA-II 2x4 8 2x4 8

HYDRO MASSANJORE 2x2 4 2x2 4RAMAM 4x12.5 50 4x12.5 50TISTA 9X7.5 67.5 9X7.5 67.5MICRO HYDEL 7.51 6.19PPSP 4X225 900 4X225 900

TOTAL HYDRO 1064.0 1062.7

GAS TURBINE HALDIA 2x20 40 2x20 40SILIGURI 1x20 20 1x20 20KASBA 2x20 40 2x20 40

TOTAL G.T. 100 100

CESC TITAGARH 4x60 240 4x60 240THERMAL N.COSSIPORE 2x30+2x50 160 100

SOUTHERN 2x67.5 135 2x67.5 135BUDGE-BUDGE 2X250 500 2X250 500

TOTAL 1035 975GRAND TOTAL THERMAL+HY+GT 6864 6708

OPTCL SYSTEM

WBSETCL SYSTEM


ERLDC:POWERGRID

ALL FIGURES IN MWSYSTEM STATION INS CAP EFF CAP

UNITS TOTAL UNITS TOTAL

SIKKIM HYDRO 32.89 32.89DIESEL 5 5

TOTAL 37.89 37.89

SYSTEM STATION INS CAP EFF CAPUNITS TOTAL UNITS TOTAL

NTPC FARAKKA NTPC 3x200+2x500 1600 3x200+2x500 1600KAHALGAON NTPC 4X210+2x500 1840 4X210+2x500 1840TALCHAR NTPC 2X500 1000 2X500 1000

TOTAL NTPC 4440 4440

NHPC RANGIT NHPC 3 x 20 60 3 x 20 60TEESTA V 3 x 170 510 3 x 170 510

CHPS CHUKHA CHPC 4x84 336 4x84 336KURICHU HEP 4 x 15 60 4 x 15 60

TALA THPS 6 x 170 1020 6 x 170 1020

SYSTEM STATION INS CAP EFF CAP

THERMAL 15944 15661DIESEL 5 5

E.REGION HYDRO 4054 4053GT 190 190TOTAL 20193 19909

TOTAL TOTAL

CENTRAL SECTOR

SIKKIM SYSTEM

EASTERN REGION


ERLDC:POWERGRID

Annexure III Captive Power Stations in Eastern Region and their Capacities


POWER SATION INSTALLED CAPACITY TOTALSYSTEM (MW) (MW)

NALCO 8 X120 (ANGUL) 9603X18.5 (DAMANJODI) 55.5

ICCL 2X54 108HPCL(INDAL) 1X67.5 67.5HINDAL 2 X 100 200RSP(ROURKELA) 5X25+2X60+1X3 248FACOR(BHADRAK) 2X10.5 21IDCOL (BARAGARH) 9.5 9.5

ORISSA KALINGO IRON 3X4 12ORIENT PAPER MILLS 1X8+1X4.5+2X3+1X1.2 19.7ORISSA TEXTILES 1X2+1X2.5+1X0.688 5.188PPL 2X16+1X4+2X1 38ISPAT ALLOYS 2X4.33+2X5.4+2X10.5 40.46FCI (TALCHER) 1X28.35 28.35KMCL(NINL), Duburi 2X19.95 38.5NB FERRO ALLOYS LTD. 1X30 30BHUSAN STEEL 1 X 40 + 1 X 60 100OSWAL (PARADEEP) 2 X 55 110VEDANTA (LANJIGARH) 1 X 30 30TATA SPONGEIRON( JODA ) 1X18.5 18.5SHYAM DRI( PANDOL, SAMBALPUR) 1X30 30ARATI STEEL (GHANTIKHAL, CUTTACK) 1X40 40BHUSAN STEEL & STRIPS(M'MUNDALI) 1X33+1X77 110ZINDAL STAILESS LTD. 1X125 125TOTAL 2445.20FCI 80 80

BIHAR USHA MARTIN 25 25BCCL REHLA 1X30 30TOTAL 135JOJOBERA 2X120 + 67.5 307.5BSL 2X55+3X60+1X12 302TISCO 1X67.5+3X30+1X25

JHARKHAND (EXCL. DG SETS) 1X12.5+1X20 215BIHAR CAUSTIC & CHICAL LTD 30TOTAL 855DSP 2X60+4X5 140IISCO 2X10+2X20 60DPSCO 14.2

W.BENGAL KESORAM REYON 6HALDIA REFINERY (IOC ) 84.5ELECTRO STEEL CASTING LTD. 12HALDIA PETROCHEMICALS LTD. 75.5TOTAL 392.2COAL INDIA LTDECL 20

COAL INDIA LTD BCCL 49.6CCL 70.3NEC 1TOTAL CIL 140.9

REGION TOTAL 3968

CAPTIVE POWER STATIONS IN EASTERN REGION AS ON 31.03.2008

ERLDC:POWERGRID

Annexure : IV UI Rate at different frequencies

0.00

2.00

4.00

6.00

8.00

10.00

12.00

48.96

49.08

49.20

49.32

49.44

49.56

49.68

49.80

49.92

50.04

50.16

50.28

50.40

50.52

Freq (Hz)

Rs/

kWh

Oct'04Apr'04Apr'03Apr'07Jan'08


ERLDC:POWERGRID

Annexure V : Variable cost and cumulative installed capacity of Thermal Power Generating Stations and respective Break even Freq for

Merit order despatch

ER (except Hydro) Variable Cost and Cumulative Installed Capacity of Power Generating Stations

50

70

90

110

130

150

170

190

IBVA

LLE

Y

TALC

HER

TSTP

P

BUD

GEB

UD

GE

ICC

L

BAK

RES

WAR

ME

JIA

CH

AND

RAP

UR

BO

KAR

O -

B

KOLA

GH

AT

NA

LCO

DU

RG

APU

R

SOU

THE

RN

TEN

UG

HA

T

PAT

RAT

U

TITA

GA

RH

BAN

DEL

FAR

AKK

A

KAH

ALG

AO

N( S

tage

I &

II)

SAN

TALD

IH

SAG

ARD

IGH

I

DPL

BAR

AU

NI

MU

ZZAF

FPU

R

N. C

OS

SIPO

RE

Varia

ble

Cos

t (Ps

/U)

0

2000

4000

6000

8000

10000

12000

14000

16000

Cum

ulat

ive

inst

alle

d C

apac

ity o

f in

MW

Cum.Capacity

Variable Cost

SL. NO. AGENCY NAME OF POWER STATION CAPACITY

(MW)VARIABLE COST (Ps) FUEL TYPE Cum. Cap.(MW)

Breakeven freq (HZ)1 GRIDCO/OPGC IBVALLEY 420 57 COAL 420 50.342 GRIDCO TALCHER 460 61 COAL 880 50.343 NTPC TSTPP 1000 67 COAL 1880 50.344 WBSEB/CESC BUDGEBUDGE 500 90 COAL 2380 50.265 GRIDCO/CPP ICCL 40 94 COAL 2420 50.266 WBSEB BAKRESWAR 630 94 COAL 3050 50.267 DVC MEJIA 1340 96 COAL 4390 50.268 DVC CHANDRAPUR 750 99 COAL 5140 50.249 DVC BOKARO - B 630 103 COAL 5770 50.24

10 WBSEB KOLAGHAT 1260 105 COAL 7030 50.2211 GRIDCO/CPP NALCO 150 110 COAL 7180 50.2212 DVC DURGAPUR 350 110 COAL 7530 50.2213 WBSEB/CESC SOUTHERN 135 112 COAL 7665 50.2214 TVNL/JSEB TENUGHAT 420 115 COAL 8085 50.2015 JSEB PATRATU 770 117 COAL 8855 50.2016 WBSEB/CESC TITAGARH 240 117 COAL 9095 50.2017 WBSEB BANDEL 530 119 COAL 9625 50.2018 NTPC FARAKKA 1600 120 COAL 11225 50.2019 NTPC KAHALGAON( Stage I & II) 1840 125 COAL 13065 50.1820 WBSEB SANTALDIH 730 126 COAL 13795 50.1821 WBSEDCL SAGARDIGHI 600 127 COAL 14395 50.1822 WBSEDCL/DPL DPL 690 129 COAL 15085 50.1823 BSEB BARAUNI 220 156 COAL 15305 50.124 BSEB MUZZAFFPUR 220 188 COAL 15525 50.0425 WBSEB/CESC N. COSSIPORE 130 190 COAL 15655 50.04


ERLDC:POWERGRID

Annexure VI(a) Format for Category A Message

Eastern Regional Load Despatch Centre POWER GRID CORPORATION OF INDIA LIMITED

14 Golf Club Road, Tollygunje, Kolkata 700033 Tel.: 033-24235435, FAX: 033-24235809 web:www.erldc.org

FAX MESSAGE

Reference: ERLDC/OD/A/_____ Date :_________ Time :______ FROM : SCE: ERLDC, KOLKATA TO: SCE : BSEB/JSEB/DVC/ OPTCL/WBSETCL/SIKKIM Sub: Low frequency operation and request to restrict to drawal within

Schedule. The system frequency is below 49.50 Hz. At present Over drawal by your State is as follows: Your specific reference is invited to Clause 6.4.4 of IEGC which states that “the States through their SLDCs shall always endeavour to restrict their net drawal from the Grid to within their respective drawal schedules whenever the system frequency is below 49.5 Hz. and when the frequency falls below 49.0 Hz. requisite load shedding shall be carried out in the concerned State(s) to curtail the overdrawal.” You are therefore requested to take necessary measures to curtail your overdrawal to help in maintaining system frequency above 49.5 Hz.

SHIFT CHARGE ENGINEER ERLDC


Contituent/s Quatum of Overdrawal ( MW) Frequency(Hz)

ERLDC:POWERGRID

Annexue VI(b) Format for Category B Message


14 Golf Club Road, Tollygunje, Kolkata 700033 Tel.: 033-24235435, FAX: 033-24235809 web:www.erldc.org

FAX MESSAGE

Reference: ERLDC/OD/B/_____ Date :_________ TOO :______ FROM : SCE , ERLDC, KOLKATA TO: SCE : BSEB/JSEB/DVC/ OPTCL/WBSETCL/SIKKIM Copy To: 1. Chief Engineer: SLDC/POWER Depatrment BSEB/JSEB/DVC/ OPTCL/WBSETCL/SIKKIM Sub: Intimation of violation of Clause 6.4.4 of IEGC for Notice for immediate action for

restricting over drawal for avert threat to system security under clause 6.4.9 and 29(1) of Indian Electricity Act 2003.

This has reference to our earlier messages on the above subject. Inspite of our requests, over drawal by your State is not reduced and at present the overdrawal is as follows: In this regard we would bring to your reference the clause 6.4.4. of IEGC which states that when the frequency falls below 49.0 Hz, requisite load shedding would be carried out by the concerned State(s) to curtail the over drawal. Further it is a matter of serious concern that despite low frequency conditions in the grid, the over drawal by your state is continuing which is a threat to system security. You are once again requested to restrict your drawal within schedule and inform the details of action taken. Please note that these directions are being issued in line with Clause 6.4.9 of IEGC and Section 29(1) of Indian Electricity Act 2003 and non-compliance of the same would be construed as violation of IEGC and IE Act 2003. You are therefore requested to take necessary measures to curtail your overdrawal to help in maintaining system frequency above 49.20 Hz. . Please treat this message as most urgent and act immediately.

SHIFT CHARGE ENGINEER ERLDC


Contituent Quatum of Overdrawal ( MW) Frequency(Hz)

ERLDC:POWERGRID

Annexure VI( c): Format for Category C message


14 Golf Club Road, Tollygunje, Kolkata 700033 Tel.: 033-24235435, FAX: 033-24235809 web:www.erldc.com

FAX MESSAGE

Reference: ERLDC/OD/C/_____ Date :_________ Time :______ FROM : SCE , ERLDC, KOLKATA TO: SCE : BSEB/JSEB/DVC/ OPTCL/WBSETCL/SIKKIM Copy To: 1. Chief Engineer: SLDC/POWER Depatrment BSEB/JSEB/DVC/ OPTCL/WBSETCL/SIKKIM Sub: Intimation of violation of Clause 6.4.4 of IEGC and 29(2)/29(3) of Indian Electricity Act

2003 on continued overdrawal at system frequency below 49.00Hz and request for immediate action for curtailing the Over drawal in the interest of grid security.

Please refer ERLDC notice issued vide reference No.ERLDC/OD/B/__________ dated _______TOO_________ directing you to restrict your drawal and carry out manual load shedding in your system. However, the over drawal by your State at low frequency is continuing resulting in threat to system security and violation of Clause 6.4.4 of IEGC and Section 29(2)/29(3) of IE Act 2003 by not complying with ERLDC’s instructions. At the moment the over drawal by your State is as follows: Please note that non-compliance of RLDC directions would be reported to CERC(as per CERC order Dtd. 16/10/08 against suo-motu petition No.115/2008) for action under section 29 of IE Act 2003. You are requested to immediately curtail your over-drawal to help in maintaining system frequency above 49.00 Hz.

SHIFT CHARGE ENGINEER ERLDC/KOLKATA


Contituent Quatum Overdrawal ( MW) Frequency(Hz)

ERLDC:POWERGRID

Annexure-VII Format for Overdrawal Message to NLDC/Other RLDCs


14 Golf Club Road, Tollygunje, Kolkata 700033 Tel.: 033-24235435, FAX: 033-24235809 web:www.erldc.com

FAX MESSAGE

Reference: ERLDC/OD/NLDC/_____ Date :_________ TOO :______ FROM : SCE , ERLDC, KOLKATA TO: SCE : NLDC Copy To: 1. SCE : NRLDC/WRLDC/NERLDC 2. ED(SO)/ED(NLDC)

Sub: Curtailment of overdrawal / Request for load shedding to avoid low frequency operation

The system frequency of the NEW Grid is around 49 Hz or below. The present net exchange of Eastern system at all its AC tie lines with other regions is as below:

Scheduled interchange (MW) at all AC interconnections with other regions

Actual Interchange (MW) at all AC interconnections with other regions

It is observed that following regions are overdrawing as below at the AC interconnections of ER at a frequency around or below 49 .0 Hz . Region Schedule Drawal (MW) Actual Drawal (MW) In view of secured system operation request kindly take up the matter with concerned RLDC/s for curtailment of overdrawal as per the provision of clause 6.4.4 of IEGC . Matter may kindly be treated as most urgent

Shift Charge Engineer ERLDC, Kolkata


ERLDC:POWERGRID

Annexure VIII List of 400/220kV ICTs and their tap positions

S U B -S T A T IO N C A P A C IT Y T A P(M V A )

B IN A G U R I 2 X 3 1 5 1 0N E W P U R N E A 2 X 3 1 5 1 1

M U Z A F F A R P U R 2 X 3 1 5 9M A L D A 2 X 3 1 5 1 2

S A S A R A M 2 X 3 1 5 1 1B IH A R S H A R IF 3 X 3 1 5 1 4

P A T N A 2 X 3 1 5 9F A R A K K A 1 X 3 1 5 1 1M A IT H O N 2 X 3 1 5 1 3

R A N C H I 2 X 3 1 5 7JA M S H E D P U R 2 X 3 1 5 1 5

P A R U L IA 2 X 3 1 5 1 1B A K R E S W A R 2 X 3 1 5 1 1A R A M B A G H 2 X 3 1 5 1 5

JE E R A T 3 X 3 1 5 1 3S U B H A S G R A M 2 X 3 1 5 1 1

K O L A G H A T 2 X 3 1 5 1 2B A R IP A D A 1 X 3 1 5 7R E N G A L I 2 X 3 1 5 1 2

R O U R K E L A 2 X 3 1 5 1 0T A L C H E R 2 X 3 1 5 1 3

M E R A M U N D A L I 2 X 3 1 5 1 1IN D R A V A T I 2 x 3 1 5 9

JE Y P O R E 2 X 3 1 5 1 6T A P 1 : 4 4 0 /2 2 0 , 9 : 4 0 0 /2 2 0 , 1 7 : 3 6 0 /2 2 0


ERLDC:POWERGRID

Annexure: IX

SL LENGTH REACTORS CAPACITYNO LINE/SUB-STN ( KM ) IN MVAR REMARKS

BUS LINE END

1 FARAKKA-JEERAT-I 238 1X50 JEERAT2 SAGARDIGHI-SUBHASGRAM 236 1X50 SUBHASGRM

1X63 SAGARDIGHI3 FARAKKA-PARULIA-I 150 1X50 FARAKKA4 PPSP-PARULIA-I 185 1X50 PARULIA8 K'GAON-B'SHARIFF-I 196 1X50 B'SHARIFF9 K'GAON-B'SHARIFF-II 196 1X50 B'SHARIFF

11 K'GAON-MAITHON-I 172 1X50 MAITHON12 K'GAON-MAITHON-II 172 1X50 MAITHON15 JAMSHEDPUR-R'KELA-I 174 1X50 ROURKELA SW ITCHABLE16 JAMSHEDPUR-R'KELA-II 174 1x50 ROURKELA17 ROURKELA-TALCHER I 175 1X50 TSTPP18 ROURKELA-TALCHER II 175 1X50 TSTPP20 BARIPADA-RENGALI 239 1x 63 RENGALI21 BAKRESWAR-ARAMBAGH 132 1X50 BAKRESW AR22 BAKRESWAR-JEERAT 162 1X50 JEERAT23 RENGALI-INDRAVATI(S/C) 356 1x50 RENGALI

1x50 INDRAVATI24 B'SHARIFF-TENUGHAT(S/C) 180 1x50 TENUGHAT NOW AT 220 KV25 MALDA-PURNEA D/C 167 2x63 MALDA26 BINAGURI-BONGAIGAON-II 216 1x63 BINAGURI SW ITCHABLE27 PURNEA-BINAGURI-II 168 1x63 PURNEA28 PURNEA-MUZAFFARPUR-I 240 1x63 PURNEA SW ITCHABLE

1x63 MZFRPR SW ITCHABLE29 PURNEA-MUZAFFARPUR-II 240 1x63 PURNEA SW ITCHABLE

1x63 MZFRPR SW ITCHABLE

30 ROURKELA -RAIGARH-I 413 1x63 ROURKELA31 ROURKELA -RAIGARH-II 413 1x63 ROURKELA32 MERAMUNDALI-JEYPORE 456 1x80 JEYPORE

1x80 MERAMUNDALI33 B'SHARIFF-PUSAULI -I 195 1x63 PUSAULI SW ITCHABLE34 B'SHARIFF-PUSAULI -II 195 1x63 PUSAULI35 PUSAULI-ALLAHABAD 1X63 PUSAULI SW ITCHABLE36 PUSAULI-SARNATH 1X63 PUSAULI SW ITCHABLE37 MUZAFFARPUR-GRKPR-I 260 1X63 MUZAFFARPUR SW ITCHABLE38 MUZAFFARPUR-GRKPR-II 260 1X63 MUZAFFARPUR SW ITCHABLE39 KAHALGAON-PATNA-I 257 1X50 PATNA40 KAHALGAON-PATNA-I 257 1X50 PATNA

41 FARAKKA(NTPC) 2X5042 BIHARSHARIFF 1X50+1X8043 KAHALGAON(NTPC) 2X5044 MAITHON 1X5045 JAMSHEDPUR 2X5046 ROURKELA 1X5047 PARULIA 1X5048 BINAGURI 2X6349 NEW PURNEA 1X6350 MUZAFFARPUR 1X6351 PATNA 1X8052 RANCHI 1X8053 RENGALI 31.5* * TERTIARY54 JEYPORE 31.5* + WINDING OF

1 x 63 400/220KV ICTs55 KOLAGHAT(W BSETCL) 1x5056 BAKRESW AR(WBSETCL) 1X5057 ARAMBAG(WBSETCL) 1X5058 JEERAT(W BSETCL) 1X50

59 TALA(BHUTAN) 1x63TOTAL 1381 2244

REACTIVE COMPENSATION DETAILSFOR 400 KV LINES / SUB-STATIONS


ERLDC:POWERGRID

Annexure X: Format for message to be issued by ERLDC for Real Time Outage clearance


14 Golf Club Road, Tollygunje, Kolkata 700033 Tel.: 033-24235435, FAX: 033-24235809 web: www.erldc.com

FAX MESSAGE

Reference: ERLDC/SD/_____ Date :_________ TOO :______ FROM : SCE , ERLDC, KOLKATA TO: SCE : BSEB/JSEB/DVC/ OPTCL/WBSETCL/SIKKIM SCE : NLDC/NRLDC/WRLDC/SRLDC/NERLDC Copy To: 1. Chief Engineer: SLDC/POWER Depatrment BSEB/JSEB/DVC/ OPTCL/WBSETCL/SIKKIM 2. SE , ERPC, Kolkata Sub: Shut down clearance Message Refer your request for shut down message no___________ dated ________. The shut down of the following element is cleared as detailed below. 1. Shutdown and duration: Sl No

Name of the Element

Agency to avail the shutdown/outage

From Date

From Time

To Date

To Time

Nature of outage

On daily basis(ODB)/Continuous

2. Nature of Shutdown: Planned(OCC cleared)/Emergency/

High Voltage / Other. 3. Reason for outage:

4. Conditions of shutdown:

a) Before actually switching off of the element prior clearance may be availed from

ERLDC. b) ERLDC may defer/postpone the shutdown if the system condition does not permit

opening of the element/s c) The shutdown must be normalised within the approved period d) ……………………………………………………………............................. e) ………………………………………………………………………………… f) …………………………………………………………................................

SHIFT CHARGE ENGINEER

ERLDC/KOLKATA


ERLDC:POWERGRID

Annexure XI Format for Weekly Reports


File No: Year: 2008-2009 / Week No: Period: From To

dd/mm/yy dd/mm/yy A) FREQUENCY PROFILE:

DATE MAXIMUM MINIMUM AVERAGEFREQ.

(Hz) (Hz) (Hz)

O/D-overdrawal During LSF O/G - overgeneration During HSF U/G-undergeneration U/D-under-drawl

B) VOLTAGE (kV) :DATE

MAX MIN MAX MIN MAX MIN MAX MIN MAX MIN

C) MAJOR GENERATION OUTAGE.SL PLANT & UNIT NO. MW CONSTI- OUTAGE RESTORATION NO. CAPACITY -TUENT Date Time Date Time

1234567

REASON/REMARKS

INSTANTANT. FREQ REMARKS

JEYPOREROURKELA BIHARSHARIFF DURGAPUR MAITHON

EASTERN REGIONAL LOAD DESPATCH CENTREPOWER GRID CORPORATION OF INDIA LTD

WEEKLY REPORT (As per IEGC Clause No.5.5.1)

ERLDC:POWERGRID

D) MAJOR TRANSMISSION OUTAGE :SL LINE / ICT KV/ OWNER REASON/NO MVA Date Time Date Time REMARKS12

E) TRANSMISSION CONSTRAINTS (if any):

F) Following elements are under breakdown :-

G) GRID DISTURBANCES (if any):

H) Messages issued by ERLDC, regarding violation of schedule,when frequency was beyond the band of 49-50.5 Hz:

I) REGULATORY MEASURES (if any) :

J) SPECIAL MENTION:

Distribution:1. C.E. TRANS.(O&M),BSEB,PATNA (D.K.Srivastava)2. C.E.,CLD,DVC,MAITHON DGM, ERLDC3. SR. G.M.(PS),GRIDCO,BHUBANESWAR4. G.M. cum C.E.,JSEB,JHARKHAND,RANCHI5. C.E,CLD,WBSEB,HOWRAH6. G.M.,FSTPS,NTPC,FARAKKA7. G.M., KhSTPS, NTPC, KAHALGAON 8. G.M., TSTPS, NTPC KANIHA9. G.M., ERTS-I, POWERGRID, PATNA10. G.M., ERTS-II, POWERGRID, KOLKATA11. C.E., (TRANS), POWER DEPTT., GOVT. OF SIKKIM12. C.E., RANGIT HPS, NHPC, RANGIT NAGAR, SOUTH SIKKIM

OUTAGE RESTORATION


ERLDC:POWERGRID

Annexure XII Format for Quarterly Reports

POWERGRID CORPORATION OF INDIA LIMITED EASTERN REGIONAL LOAD DESPATCH CENTRE

QUARTERLY REPORT (AS PER CLAUSE 5.5.2) Brief report on Regional Power System performance of the Grid Power Supply Position Month Energy Availability

(MU) Enegy Requirement (MU)

Energy Shortage(-)/Surplus(+) in %

Month, yy Month,yy Month yy

• Report on System Constraint on Regional Grid

• Low Generation Availability

• Other Constraints

• Outage of Important Transmission elements

• Important Events

• Quality of service

o Frequency Profile ( as % age of time) in the quarter Month < 49 Hz 49-49.5 Hz 49.5-50 Hz 50-50.5Hz 50.5-51 Hz > 51 Hz Month,yy Month,yy Month,yy Following Curves are enclosed

1. Annexure I . Frequency duration curve for 1st month 2. Annexure II: Frequency duration curve for the 2nd month 3. Annexure III: Frequency duration curve for the 3rd month

o Voltage profile

MAX MIN MAX MIN MAX MIN MAX MIN MAX MINMonth’yyMonth’yyMonth’yy

Jamshedpur MaithonMonth

Biharshariff Durgapur Farakka

o Other Issues Event Reporting ( clause 6.9.6) Grid incidences in ER system The system incidences those occurred during the Month, yy to Month ,yy are detailed below DGM/Grid Management


ERLDC:POWERGRID

Annexure XIII Format for written report for event reporting

(vide IEGC Clause 5.3.1)

(i) Time and date of event (ii) Location (iii) Plant and/or Equipment directly involved (iv) Description and cause of event (v) Antecedent conditions (vi) Demand and/or Generation (in MW) interrupted and durationof

interruption (vii) All Relevant system data including copies of records of all recording

instruments including Disturbance Recorder, Event Logger, DAS etc. (viii) Sequence of trippings with time. (ix) Details of Relay Flags.


(x) Remedial measure

ERLDC:POWERGRID

Annexure XIV Categorisation of Grid Incidences/Disturbances

__Op

Annexure XIV (a) Categorisation of Grid Incidents

Sl No Date Name of Element/Elements Voltage Level Frequency(Hz) Rescheduling Category of Incidence Remarks if any220kV 400kV Before After Required ?(Y/N) (1/2)

Annexure XIV (b) Categorisation of Grid Disturbance

_______________________________________________________________________ erating Procedures for Eastern Region Page 82 15-12-2008

Sl No Date Name of Element/Elements Voltage Level Frequency(Hz) Antecedant Generation % age Antecedant Lost %age Category RemarksTripped 220kV 400kV Before After Generation(MW) Lost (MW) Loss of Gen Load(MW) Load(MW) Load Loss (1/2/3/4/5)

ERLDC:POWERGRID

AnnexureXV(a) Monsoon Flow Gate -I


O R IS S A

S ikk im

B IH A R

JH A R K H A N DW E S T B E N GA L

D V CD V C

B h u ta n

A ssamU tta r P ra de sh

C ha ttisga rh

A nd h ra P ra d esh

G o ra kh pu r

B a lia

A lhb ad /S a rn a thR iha n d

S ah up u ri

R a iga rh

K o rb a /R a iga rh

B h u ta n

S a la ka ti

K o la r U S ille ru

S h iligu riP u rn e aM u zfp r

B h rs rf

P a tn aP u sau li

M a ld a

K h S T P P F S T P P

S a g a rd ig h iB K T P P

J e e ra t

S u b h asg ra mK T P P

P P S P

M a ith o n

Ja m sed p u r

B a rip ad aR o u rke la

A rm b g

R e n g a liT S T P P

M e ra m u n d a li

In d ra va ti

Je yp o re

A x is o f S e pe ra tio n

O R IS S A

S ikk im

B IH A R


D V CD V C

B h u ta n


C ha ttisga rh


G o ra kh pu r

B a lia


S ah up u ri

R a iga rh


B h u ta n

S a la ka ti



B h rs rf

P a tn aP u sau li

M a ld a



J e e ra t


P P S P

M a ith o n

Ja m sed p u r


A rm b g


M e ra m u n d a li

In d ra va ti

Je yp o re

O R IS S A

S ikk im

B IH A R


D V C

O R IS S A

S ikk im

B IH A R


D V CD V C

B h u ta n


C ha ttisga rh


G o ra kh pu r

B a lia


S ah up u ri

R a iga rh


B h u ta n

S a la ka ti



B h rs rf

P a tn aP u sau li

M a ld a



J e e ra t


P P S P

M a ith o n

Ja m sed p u r


A rm b g


M e ra m u n d a li

In d ra va ti

Je yp o re

A x is o f S e pe ra tio n

Monsoon flow gate-I ( Sept-2008)

0

500

1000

1500

2000

2500

3000

3500

4000

4500

5000

01 02 03 04 05 07 08 09 10 12 13 14 15 16 18 19 20 21 23 24 25 26 27 29 30

MW

-1000

-500

0

500

1000

1500

2000

2500

3000

3500Total Flow gate PRN-MZF MWFRK-KHG MWNR Drawal

ERLDC:POWERGRID

Annexure XV(b): Monsoon Flow Gate II

__________Operating P

U Silleru

ORISSA

Sikkim

BIHAR

JHARKHANDWEST BENGAL

DVC

DVC

Bhutan

AssamUttar Pradesh

Chattisgarh

Andhra Pradesh

Gorakhpur

Balia

Alhbad/SarnathRihand

Sahupuri

Raigarh

Korba/Raigarh

Bhutan

Bongaigaon

Salakati

Kolar

ShiliguriPurneaMuzfpr

Bhrsrf

PatnaPusauli

Malda

KhSTPP FSTPP

SagardighiBKTPP

Jeerat

SubhasgramKTPP

PPSP

Maithon

Jamsedpur

BaripadaRourkela

Armbg

RengaliTSTPP

Meramundali

Indravati

Jeypore

Axis of separation

U Silleru

ORISSA

Sikkim

BIHAR


DVC

DVC

Bhutan

AssamUttar Pradesh

Chattisgarh

Andhra Pradesh

Gorakhpur

Balia


Sahupuri

Raigarh

Korba/Raigarh

Bhutan

Bongaigaon

Salakati

Kolar


Bhrsrf

PatnaPusauli

Malda

KhSTPP FSTPP

SagardighiBKTPP

Jeerat

SubhasgramKTPP

PPSP

Maithon

Jamsedpur

BaripadaRourkela

Armbg

RengaliTSTPP

Meramundali

Indravati

Jeypore

ORISSA

Sikkim

BIHAR


DVC

DVC

Bhutan

AssamUttar Pradesh

Chattisgarh

Andhra Pradesh

Gorakhpur

Balia


Sahupuri

Raigarh

Korba/Raigarh

Bhutan

Bongaigaon

Salakati

Kolar


Bhrsrf

PatnaPusauli

Malda

KhSTPP FSTPP

SagardighiBKTPP

Jeerat

SubhasgramKTPP

PPSP

Maithon

Jamsedpur

BaripadaRourkela

Armbg

RengaliTSTPP

Meramundali

Indravati

Jeypore

Axis of separation

_______________________________________________________________ rocedures for Eastern Region Page 84 15-12-2008

Sept 2007 ( High Hydro in SR and Orissa

-500

0

500

1000

1500

2000

01 02 03 05 06 07 09 10 12 13 14 16 17 19 20 21 23 24 26 27 28 30

MW

Total Flow Gate TSTPP to RKL MW Rengali-Kolaghat

ERLDC:POWERGRID

Annexure XV( c) Winter Flow gate I

__________Operating P

_______________________________________________________________ rocedures for Eastern Region Page 85 15-12-2008

0.00

500.00

1000.00

1500.00

2000.00

2500.00

1-Dec3-Dec5-Dec7-Dec10-Dec12-Dec14-Dec16-Dec19-Dec21-Dec23-Dec25-Dec28-Dec30-Dec1-Dec4-Dec6-Dec8-Dec11-Dec13-Dec15-Dec17-Dec20-Dec22-Dec24-Dec27-Dec29-Dec31-Dec

Total Flow gate MWFarakka-Malda D/C

Farakka-Kahalgaon D/C

Period : Dec’06 & Dec 07

FSC at PRN kept out of service

2006 2007(Source SCDA data ERLDC)

0.00

500.00

1000.00

1500.00

2000.00

2500.00

1-Dec3-Dec5-Dec7-Dec10-Dec12-Dec14-Dec16-Dec19-Dec21-Dec23-Dec25-Dec28-Dec30-Dec1-Dec4-Dec6-Dec8-Dec11-Dec13-Dec15-Dec17-Dec20-Dec22-Dec24-Dec27-Dec29-Dec31-Dec





2006 2007





2006 2007(Source SCDA data ERLDC)

ORISSA

Sikkim

BIHAR


DVC

DVC

Uttar Pradesh

Chattisgarh

Andhra Pradesh

Gorakhpur

Balia


Sahupuri

Raigarh

Korba/Raigarh

Kolar U Silleru


Bhrsrf

PatnaPusauli

Malda

KhSTPP FSTPP

SagardighiBKTPP

Jeerat

SubhasgrKTPP

PPSP

Maithon

Jamsedpur

BaripadaRourkela

Armbg

RengaliTSTPP

Meramundali

Indravati

Jeypore

ORISSA

Sikkim

BIHAR


DVC

DVC

Uttar Pradesh

Chattisgarh

Andhra Pradesh

Gorakhpur

Balia


Sahupuri

Raigarh

Korba/Raigarh

Kolar U Silleru


Bhrsrf

PatnaPusauli

Malda

KhSTPP FSTPP

SagardighiBKTPP

Jeerat

SubhasgrKTPP

PPSP

Maithon

Jamsedpur

BaripadaRourkela

Armbg

RengaliTSTPP

Meramundali

Indravati

Jeypore

ERLDC:POWERGRID

Annexure XV( d ) : Winter Flow Gate II

________Operating

BhutanBhutanBhutanBhutan

_________________________________________________________________ Procedures for Eastern Region Page 86 15-12-2008

ORISSA

Sikkim

BIHAR


DVCDVC

AssamUttar Pradesh

Chattisgarh

Andhra Pradesh

Gorakhpur

Balia


Sahupuri

Raigarh

Korba/Raigarh

Salakati

Kolar

GazuwakaU Silleru


Bhrsrf

PatnaPusauli

Malda

KhSTPP FSTPP

SagardighiBKTPP

Jeerat

SubhasgramKTPP

PPSPMaithon

Jamsedpur

BaripadaRourkela

Armbg

RengaliTSTPP

Meramundali

Indravati

Jeypore

Axis of Seperation

Axis of Seperat

ORISSA

Sikkim

BIHAR


DVC

ORISSA

Sikkim

BIHAR


DVCDVC

AssamUttar Pradesh

Chattisgarh

Andhra Pradesh

Gorakhpur

Balia


Sahupuri

Raigarh

Korba/Raigarh

Salakati

Kolar

GazuwakaU Silleru


Bhrsrf

PatnaPusauli

Malda

KhSTPP FSTPP

SagardighiBKTPP

Jeerat

SubhasgramKTPP

PPSPMaithon

Jamsedpur

BaripadaRourkela

Armbg

RengaliTSTPP

Meramundali

Indravati

Jeypore

Axis of Seperation

Axis of Seperat

Angular Diff Vidyachal (N-W Bus)(degree) vs Total Axis & & NR Import

( 12.3.07 /2000 Hrs to 13.3.07 /08:00 Hrs)

0

500

1000

1500

2000

2500

3000

20:0

0

20:4

8

21:3

7

22:2

5

23:1

4

0:02

0:51

1:39

2:28

3:16

4:05

4:53

5:42

6:30

7:19

-20

-10

0

10

20

30

40

50

60

70

Axis Total NR-WRAngle

Both N-1 Criteria andStability criteria (>30°)violated

Angular Diff Vidyachal (N-W Bus)(degree) vs Total Axis & & NR Import( 12.3.07 /2000 Hrs to 13.3.07 /08:00 Hrs)

0

500

1000

1500

2000

2500

3000

20:0

0

20:4

8

21:3

7

22:2

5

23:1

4

0:02

0:51

1:39

2:28

3:16

4:05

4:53

5:42

6:30

7:19

-20

-10

0

10

20

30

40

50

60

70


Angular Diff Vidyachal (N-W Bus)(degree) vs Total Axis & & NR Import( 12.3.07 /2000 Hrs to 13.3.07 /08:00 Hrs)

0

500

1000

1500

2000

2500

3000

20:0

0

20:4

8

21:3

7

22:2

5

23:1

4

0:02

0:51

1:39

2:28

3:16

4:05

4:53

5:42

6:30

7:19

-20

-10

0

10

20

30

40

50

60

70


Both N-1 Criteria andStability criteria (>30°)violated

ERLDC:POWERGRID

Annexure XVI ( List of Important Elements) Tie Lines


SL TIE-LINE OWNED BY LENGTH COND. VOLTS NO.OFNO END-1 END-2 (KM) (TYPE) (KV) CKTS.1 FARAKKA-JEERAT POWERGRID POWERGRID WBSETCL 238 TW.MOOSE 400 S/C2 FARAKKA-SAGARDIGHI POWERGRID NTPC WBPDCL 67 TW.MOOSE 400 S/C3 JEERAT-SUBHASGRAM POWERGRID WBSETCL POWERGRID 80 TW.MOOSE 400 S/C4 PARULIA-PPSP WBSETCL POWERGRID WBSETCL 185 TW.MOOSE 400 D/C5 BINAGURI-BONGAIGAON POWERGRID POWERGRID(ER) POWERGRID(NER) 216 TW.MOOSE 400 D/C6 JEYPORE-GAZUWAKA POWERGRID POWERGRID(ER) POWERGRID(SR) 220 TW.MOOSE 400 D/C7 JEYPORE-MERAMUNDALI POWERGRID POWERGRID(ER) OPTCL 456 TW.MOOSE 400 S/C8 INDRAVATI-INDRAVATI OPTCL POWERGRID(ER) OPTCL 1 TW.MOOSE 400 S/C9 KOLAGHAT-BARIPADA WBSETCL & OPTCL WBSETCL POWERGRID(ER) 174 TW.MOOSE 400 S/C10 TSTPP-MERAMUNDALI POWERGRID NTPC OPTCL 51 TW.MOOSE 400 D/C11 BINAGURI-TALA I & II POWERLINKS POWERGRID THEP 115 TW.MOOSE 400 D/C12 BINAGURI-MALBASE POWERLINKS POWERGRID THEP 121 TW.MOOSE 400 S/C13 MUZZFARPUR-GOROKHPUR POWERLINKS POWERGRID(ER) POWERGRID(NR) 261 QUAD-MOOSE 400 D/C14 PATNA-BALIA POWERGRID POWERGRID(ER) POWERGRID(NR) 195 QUAD-MOOSE 400 D/C15 BIHARSHARIFF-BALIA POWERGRID POWERGRID(ER) POWERGRID(NR) 242 QUAD-MOOSE 400 D/C16 SASARAM -SARNATH POWERGRID POWERGRID(ER) POWERGRID(NR) 76 TW.MOOSE 400 S/C17 SASARAM -ALLAHABAD POWERGRID POWERGRID(ER) POWERGRID(NR) 271 TW.MOOSE 400 S/C18 ROURKELA-RAIGARH POWERGRID POWERGRID(ER) POWERGRID(WR) 212 TW.MOOSE 400 D/C19 DEHRI--PUSUALI BSEB BSEB POWERGRID 64 ZEBRA 220 S/C20 PUSUALI-SAHUPURI BSEB & UPPCL POWERGRID UPPCL 72 ZEBRA 220 S/C21 ARRAHA-KAHAGAUL POWERGRID POWERGRID BSEB 50 ZEBRA 220 D/C22 WARIA-BIDHANNAGAR DVC & WBSETCL DVC WBSETCL 17 ZEBRA 220 D/C23 BALIMELA-U.SILLERU OPTCL & APTRANSCO OPTCL APTRASCO 24 ZEBRA 220 S/C24 JODA-JAMSHEDPUR OPTCL & DVC OPTCL DVC 135 ZEBRA 220 S/C25 JODA-RAMCHANDRAPUR OPTCL & JSEB OPTCL JSEB 127 ZEBRA 220 S/C26 BUDHIPADAR-KORBA OPTCL & CSEB OPTCL CHATTISGARH 180 ZEBRA 220 D/C27 BUDHIPADAR-RAIGARH POWERGRID OPTCL CHATTISGARH 81 ZEBRA 220 S/C28 PATRATU-BODHGAYA BSEB & JSEB JSEB BSEB 136 ZEBRA 220 T/C29 PATNA-KHAGUAL BSEB POWERGRID BSEB 25 ZEBRA 220 S/C30 TENUGHAT-BIHARSHARIFF BSEB & JSEB JSEB BSEB 182 TW.MOOSE 220 S/C31 CHANDIL-SANTALDIH WBSETCL & JSEB JSEB WBSETCL 105 ZEBRA 220 S/C32 TSTPP-MERAMUNDALI OPTCL NTPC OPTCL 40 ZEBRA 220 D/C33 TSTPP-RENGALI OPTCL NTPC OPTCL 40 ZEBRA 220 S/C34 TSTPP-TALCHER OPTCL NTPC OPTCL 30 ZEBRA 220 S/C35 FARAKKA-LALMATIA POWERGRID NTPC JSEB 79 ZEBRA 220 S/C36 B'SHARIF-B'SHARIF POWERGRID POWERGRID BSEB 0 ZEBRA 220 T/C37 MAITHON-K'SWARI DVC POWERGRID DVC 8 ZEBRA 220 D/C38 PARULIA(PG)-PARULIA(DVC) DVC POWERGRID DVC 1 ZEBRA 220 D/C39 BISRA-TARKERA OPTCL POWERGRID OPTCL 15 ZEBRA 220 D/C40 JEYPORE-JAYNAGAR OPTCL POWERGRID OPTCL 1 ZEBRA 220 D/C41 RENGALI-RENGALI OPTCL POWERGRID OPTCL 1 ZEBRA 220 D/C42 BARIPADA-BALASORE OPTCL POWERGRID OPTCL 77 ZEBRA 220 D/C43 JAMSHEDPUR-RAMCHANDRAPUR DVC & JSEB POWERGRID JSEB 0 ZEBRA 220 D/C44 PARULIA-BIDHANNAGAR WBSETCL POWERGRID WBSETCL 11 TW.MOOSE 220 S/C45 BINAGURI-NJP POWERGRID POWERGRID WBSETCL 0.2 ZEBRA 220 S/C46 SUBASHGRAM-LAXMIKANTPUR WBSETCL POWERGRID WBSETCL 43 ZEBRA 220 S/C47 SUBASHGRAM-JEERAT WBSETCL POWERGRID WBSETCL 63 ZEBRA 220 S/C48 BIRPARA- CHUKHA POWERGRID POWERGRID POWERGRID 76 ZEBRA 220 D/C49 BIRPARA-MALBASE POWERGRID POWERGRID POWERGRID 40 ZEBRA 220 S/C50 MUZZFARPUR-KANTI POWERGRID POWERGRID BSEB 22 ZEBRA 220 D/C

CONNECTED SYSTEMS

ERLDC:POWERGRID

Annexure XVI… contd Tie Lines …. contd

_O

51 RANCHI-HATIA JSEB POWERGRID JSEB 34 ZEBRA 220 S/C

________________________________________________________________________ perating Procedures for Eastern Region Page 88 15-12-2008

52 CHANDIL-RANCHI JSEB JSEB POWERGRID 42 ZEBRA 220 S/C53 BIRPARA-SALAKATI POWERGRID POWERGRID(ER) POWERGRID(NER) 160 ZEBRA 220 D/C54 BARHI - B'SHARIFF BSEB & DVC DVC BSEB 170 LARK 132 S/C55 BARHI-RAJGIR BSEB & DVC DVC BSEB 125 LARK 132 S/C56 DEOGHAR-SULTANGANJ DVC & JSEB JSEB BSEB 93 PANTHER 132 S/C57 KAHALGAON-KAHALGAON POWERGRID BSEB NTPC 2 PANTHER 132 S/C58 ARRAH-ARRAH BSEB BSEB POWERGRID 3 PANTHER 132 S/C59 DUMRAON-ARRAH BSEB BSEB POWERGRID 61 PANTHER 132 S/C60 PURNEA-PURNEA BSEB BSEB POWERGRID 1 LARK 132 T/C61 DEHRI--PUSUALI POWERGRID BSEB POWERGRID 63 PANTHER 132 S/C62 KARMANASA--PUSUALI POWERGRID BSEB POWERGRID 29 PANTHER 132 S/C63 KARMANASA-SAHUPURI BSEB & UPPCL BSEB UPPCL 27 PANTHER 132 S/C64 KARMANASA-CHANDAULI BSEB & UPPCL BSEB UPPCL 25 PANTHER 132 S/C65 SONENAGAR - RIHAND BSEB & UPPCL BSEB UPPCL 139 PANTHER 132 S/C66 MAITHON-JAMTARA DVC & JSEB DVC JSEB 100 PANTHER 132 S/C67 KHARAGPUR-KHARAGPUR DVC DVC WBSETCL 1 PANTHER 132 S/C68 KOLAGHAT-KOLAGHAT DVC DVC WBSETCL 1 PANTHER 132 S/C69 MACHKUND-VIZAG OPTCL & APTRANSCO OPTCL APTRANSCO 160 LARK 132 S/C70 JODA-KENDPOSI OPTCL & JSEB OPTCL JSEB 48 PANTHER 132 S/C71 BARIPADA-RAIRANGPUR OPTCL POWERGRID OPTCL 70 PANTHER 132 S/C72 BARIPADA-BARIPADA OPTCL POWERGRID OPTCL 11 PANTHER 132 S/C73 GARWA-SONENAGAR BSEB & JSEB JSEB BSEB 104 PANTHER 132 S/C74 LALMATIA-SABOUR BSEB & JSEB JSEB BSEB 72 PANTHER 132 S/C75 CHANDIL-MANIQUE JSEB & DVC JSEB DVC 1 PANTHER 132 D/C76 PATRATU-PATRATU JSEB & DVC JSEB DVC 3 LARK 132 S/C77 GARWA-RIHAND JSEB & UPPCL JSEB UPPCL 30 PANTHER 132 S/C78 RANGIT-RAMMAM POWERGRID NHPC WBSETCL 27 ZEBRA 132 S/C79 KAHALGAON-SABOUR POWERGRID NTPC BSEB 37 PANTHER 132 S/C80 KAHALGAON-LALMATIA POWERGRID NTPC JSEB 34 PANTHER 132 S/C81 BIRPARA-BIRPARA WBSETCL POWERGRID WBSETCL 1 PANTHER 132 D/C82 MALDA-MALDA WBSETCL POWERGRID WBSETCL 6 PANTHER 132 D/C83 NJP-NBU WBSETCL POWERGRID WBSETCL 8 PANTHER 132 D/C84 PURULIA-PURULIA WBSETCL & DVC WBSETCL DVC 1 PANTHER 132 S/C85 RANGIT - MELLI SIKKIM NHPC SIKKIM 32.5 PANTHER 132 D/C86 RANGIT - MELLI POWERGRID NHPC SIKKIM 37 LARK 66 S/C87 GANGTOK - MELLI POWERGRID POWERGRID SIKKIM 37 PANTHER 132 S/C88 GANGTOK - GANGTOK POWERGRID POWERGRID SIKKIM 0 PANTHER 132 D/C89 KALINGPONG-MELLI WBSETCL & SIKKIM WBSETCL SIKKIM 15 DOG 66 D/C90 NJP-MELLI POWERGRID POWERGRID SIKKIM 90 PANTHER 132 S/C

ERLDC:POWERGRID

Annexure XVI … contd Other Important Lines

_O

OTHER IMPORTANT LINES


LINE OWNED BY LENGTH COND. VOLTS NO.OFEND-1 END-2 (KM) (TYPE) (KV) CKTS.

PTPS -TENUGHAT JSEB JSEB TVNL 53 TW. MOOSE 220 1MERAMUNDALI - BIDANASI OPTCL OPTCL OPTCL 90 TW. MOOSE 220 2RENGALI - BARIPADA OPTCL POWERGRID POWERGRID 240 TW. MOOSE 400 1KTPS - JEERAT WBSETCL WBPDCL WBSETCL 130 TW. MOOSE 400 1BAKRESWAR - JEERAT WBSETCL WBPDCL WBSETCL 162 TW. MOOSE 400 1BAKRESWAR - ARAMBAGH WBSETCL WBPDCL WBSETCL 130 TW. MOOSE 400 1PPSP - ARAMBAGH WBSEDCL WBPDCL WBSETCL 210 TW. MOOSE 400 2KTPS - ARAMBAGH WBSETCL WBPDCL WBSETCL 75 TW. MOOSE 400 1JEYPORE - INDRAVATI POWERGRID POWERGRID POWERGRID 72 TW. MOOSE 400 1INDRAVATI - RENGALI POWERGRID POWERGRID POWERGRID 356 TW. MOOSE 400 1FARAKKA - KAHALGAON POWERGRID NTPC NTPC 95 TW. MOOSE 400 2SAGARDIGHI -SUBHASGRAM POWERGRID POWERGRID POWERGRID 256.3 TW. MOOSE 400 1PARULIA - JAMSHEDPUR POWERGRID POWERGRID POWERGRID 177 TW. MOOSE 400 1MAITHON - JAMSHEDPUR POWERGRID POWERGRID POWERGRID 153 TW. MOOSE 400 2MAITHON - KAHALGAON POWERGRID POWERGRID POWERGRID 172 TW. MOOSE 400 2MAITHON - RANCHI POWERGRID POWERGRID POWERGRID 200 TW. MOOSE 400 2FARAKKA - MALDA POWERGRID NTPC POWERGRID 40 TW. MOOSE 400 2KAHALGAON BIHARSARIFF I & II POWERGRID NTPC POWERGRID 201 TW. MOOSE 400 2KAHALGAON-BIHARSARIFF III & IV POWERGRID NTPC POWERGRID 166 TW. MOOSE 400 2KAHALGAON -PATNA POWERGRID NTPC POWERGRID 257 QD. MOOSE 400 2TSTPP - ROURKELA POWERGRID NTPC POWERGRID 171 TW. MOOSE 400 2FRAKKA - PARULIA POWERGRID NTPC POWERGRID 150 TW. MOOSE 400 1TSTPP - RENGALI POWERGRID NTPC POWERGRID 24 TW. MOOSE 400 2JAMSHEDPUR - ROURKELA POWERGRID POWERGRID POWERGRID 174 TW. MOOSE 400 2MALDA - PURNEA POWERGRID POWERGRID POWERGRID 167 TW. MOOSE 400 2PURNEA - BINAGURI I & II POWERGRID POWERGRID POWERGRID 168 TW. MOOSE 400 2PURNEA - BINAGURI III & IV POWERGRID POWERGRID POWERGRID 160 QD. MOOSE 400 2PURNEA - MUZAFFARPUR POWERLINKS POWERGRID POWERGRID 240 QD. MOOSE 400 2BIHARSHARIFF-MUZAFFARPUR POWERGRID POWERGRID POWERGRID 130 TW. MOOSE 400 2BIHARSHARIFF- PUSAULI POWERGRID POWERGRID POWERGRID 195 TW. MOOSE 400 2TALA - BINAGURI I & II POWERLINKS THEP POWERGRID 115 TW. MOOSE 400 2TALA - BINAGURI IV POWERLINKS THEP POWERGRID 98 TW. MOOSE 400 1MALBASE-BINAGURI POWERLINKS BPC POWERGRID 125.1 TW. MOOSE 400 1TEESTA-V - BINAGURI POWERGRID NHPC POWERGRID 115 TW. MOOSE 400 2BIHARSHARIFF-FATUAH BSEB BSEB BSEB 40 ZEBRA 220 2BIHARSHARIFF-BODHAGYA BSEB BSEB BSEB 85 ZEBRA 220 2DEHRI-BODHGAYA BSEB BSEB BSEB 90 ZEBRA 220 2FATUAH-MTPS BSEB BSEB BSEB 92 ZEBRA 220 1WARIA-PARULIA DVC DVC DVC 21 ZEBRA 220 2WARIA-MEJIA DVC DVC DVC 34 ZEBRA 220 2CTPS-KALYANESWARI DVC DVC DVC 91 ZEBRA 220 2MEJIA-CTPS DVC DVC DVC 119 ZEBRA 220 2BOKARO-JAMSHEDPUR DVC DVC DVC 150 ZEBRA 220 2BOKARO-CTPS DVC DVC DVC 41 ZEBRA 220 2KALYANESHWARI-MEJIA DVC DVC DVC 55 ZEBRA 220 1BOKARO-RAMGARH DVC DVC DVC 55 ZEBRA 220 2PATRATU-HATIA JSEB JSEB JSEB 51 ZEBRA 220 1JEYANAGAR-U.KOLAB OPTCL OPTCL OHPC 6 ZEBRA 220 2TALCHER-NALCO OPTCL NTPC NALCO 17 ZEBRA 220 1NALCO-RENGALI HPS OPTCL NALCO OHPC 34 ZEBRA 220 1BALIMELA-JEYNAGAR OPTCL OHPC OPTCL 93 ZEBRA 220 3IBTPS - BUDHIPADAR OPTCL OPGC OPTCL 25 ZEBRA 220 3TARKERA-BUDHIPADAR OPTCL OPTCL OPTCL 120 ZEBRA 220 2U. KOLAB-THERUVALI OPTCL OHPC OPTCL 136 ZEBRA 220 1TALCHER-MERAMUNDALI OPTCL NTPC OPTCL 20 ZEBRA 220 2UIHEP-THERUVALI OPTCL OHPC OPTCL 90 ZEBRA 220 3KTPS-HOWRAH WBSETCL WBPDCL WBSETCL 71 ZEBRA 220 2ARAMBAGH-SANTALDIH WBSETCL WBSETCL WBPDCL 183 ZEBRA 220 2SANTALDIH-BIDHANNAGR WBSETCL WBDPCL WBSETCL 100 ZEBRA 220 1BIDHANNAGAR-DPL WBSETCL WBSETCL DPL 5 ZEBRA 220 1BIDHANNAGAR-BAKRESWAR WBSETCL WBSETCL WBPDCL 47 ZEBRA 220 2BAKRESWAR-GOKARNO WBSETCL WBPDCL WBSETCL 82 ZEBRA 220 2GOKARNO-SAGARDIGHI WBSETCL WBSETCL WBPDCL 39 ZEBRA 200 2DALKHOLA-PURNEA POWERGRID POWERGRID POWERGRID 41 ZEBRA 220 2BIRPARA-BINAGURI POWERGRID POWERGRID POWERGRID 80 ZEBRA 220 2NJP-BINAGURI POWERGRID POWERGRID POWERGRID 6 ZEBRA 220 2NJP-DALKHOLA POWERGRID POWERGRID POWERGRID 119 ZEBRA 220 2DALKHOLA-MALDA POWERGRID POWERGRID POWERGRID 116 ZEBRA 220 2

CONNECTED SYSTEMS

ERLDC:POWERGRID

Annexure XVI …. contd List of important Transformers

LOCATION VOLTAGE RATIO CAPACITY (MVA) OWNERSHIPJAMSHEDPUR 400/220 2X315 POWERGRID

FARAKKA 400/220 1X315 POWERGRIDPARULIA 400/220 2X315 POWERGRIDMALDA 400/220 2X315 POWERGRID

BIHARSHARIF 400/220 3X315 POWERGRIDJEYPORE 400/220 2X315 POWERGRIDRENGALI 400/220 2X315 POWERGRID

KAHALGAON 400/132 2X200 NTPCMAITHON 400/220 2X315 POWERGRID

ROURKELA 400/220 2X315 POWERGRIDSASARAM 400/220 2X315 POWERGRID

TSTPP 400/220 2X315 NTPCBINAGURI 400/220 2X315 POWERGRID

NEW PURNEA 400/220 2X315 POWERGRIDMUZAFFARPUR 400/220 2X315 POWERGRID

BARIPADA 400/220 2X315 POWERGRIDINDRAVATI 2ND 400/220 1X315 POWERGRIDSUBHASGRAM 400/220 2X315 POWERGRID

PATNA 400/220 2X315 POWERGRIDRANCHI 400/220 2X315 POWERGRID

TALCHER HVDC CONV. XMER 400/(210/√3)/210 6X(397/198.5/198.5) POWERGRIDSSRM HVDC CONV. XFER (EAST) 400/(93/√3)/93 3X(234/117/117) POWERGRID

SSRM HVDC CONV. XFER (NORTH) 400/(93/√3)/93 3X(234/117/117) POWERGRIDBIRPARA 220/132 1x50+1x100 POWERGRID

NJP 220/132 1X100 POWERGRIDPURNEA 220/132 3X100 POWERGRIDMALDA 220/132 3X50 POWERGRID

BARIPADA 220/132 1X160 POWERGRIDARRAHA 220/132 2X100 POWERGRID

GANGTOK 132/66 2X50 POWERGRIDKHAGAUL 220/132 2X100 BSEBPATRATU 220/132 2X150 JSEBBOKARO 220/132 2X150 DVC

CHANDRAPURA 220/132 2x100+2x150 DVCWARIA 220/132 2X150 DVC

INDRAVATI 400/220 1x315 OHPCMERAMUNDALI 400/220 2X315 OPTCL

JODA 220/132 2X100 OPTCLTALCHER 220/132 2X160 NTPC

BUDHIPADAR 220/132 2X160 OPTCLKOLAGHAT TPS 400/220 2X315 WBPDCL

BAKRESWAR 400/220 2X315 WBPDCLSAGARDIGHI 400/220 1X315 WBPDCL

JEERAT 400/220 3X315 WBSETCLARAMBAGH 400/220 3X315 WBSETCLSANTALDIH 220/132 1X100 WBPDCL


ERLDC:POWERGRID

Annexure XVI (contd) List of Reactors and Harmonic Filters

LENGTH REACTOR CAPACITY (MVAR)LINE/SUB-STN ( KM ) REMARKS

BUS LINE ENDFARAKKA - JEERAT-I 238 50 JEERAT

SAGARDIGHI-SUBHASGRAM 256.3 50 SUBHASHGRMPPSP-PARULIA-I 150 1X50 PARULIA

K'GAON-B'SHARIFF-I 196 1X50 B'SHARIFFK'GAON-B'SHARIFF-II 196 1X50 B'SHARIFFK'GAON-MAITHON-I 172 1X50 MAITHONK'GAON-MAITHON-II 172 1X50 MAITHON

JAMSHEDPUR-R'KELA-I 174 1X50 ROURKELA SWITCHABLEJAMSHEDPUR-R'KELA-II 174 1x50 ROURKELA

BARIPADA-RENGALI 239 1x 63 RENGALIRENGALI-INDRAVATI(S/C) 356 1x50 RENGALI

1x50 INDRAVATIMALDA-PURNEA I 167 1X63 MALDAMALDA-PURNEA II 167 1X63 MALDA

BINAGURI-BONGAIGAON-II 216 1x63 BINAGURI SWITCHABLEPURNEA-BINAGURI-II 168 1x63 PURNEA

PURNEA-MUZAFFARPUR-I 240 1x63 PURNEA SWITCHABLE1x63 MZFRPR SWITCHABLE

PURNEA-MUZAFFARPUR-II 240 1x63 PURNEA SWITCHABLE1x63 MZFRPR SWITCHABLE

ROURKELA-RAIGARH I 212.4 1x63 ROURKELAROURKELA-RAIGARH II 212.4 1X63 ROURKELA

MERAMUNDALI-JEYPORE 456 1x80 JEYPOREB'SHARIFF-SASARAM I 195 1X63 SASARAM SWITCHABLEB'SHARIFF-SASARAM II 195 1X63 SASARAM SWITCHABLESASARAM -SARNATH 76 1X63 SASARAM SWITCHABLE

SASARAM -ALLAHABAD 271 1X63 SASARAM SWITCHABLEMUZAFFARPUR-GRKPR-I 260 1X63 MUZAFFARPUR SWITCHABLEMUZAFFARPUR-GRKPR-II 260 1X63 MUZAFFARPUR SWITCHABLE

KAHALGAON-PATNA-I 257 1X50 PATNAKAHALGAON-PATNA-I 257 1X50 PATNA

RANCHI-SIPAT-II 405 1X80 RANCHIBIHARSHARIFF 1X50+1X80

MAITHON 1X50JAMSHEDPUR 2X50

ROURKELA 1X50PARULIA 1X50

BINAGURI 2X63NEW PURNEA 1X63

MUZAFFARPUR 1X63PATNA 1X80RANCHI 1X80

SASARAM (EAST) FILTER BANK 4X112SASARAM (NORTH) FILTER BANK 4X112

TALCHER FILTER BANK 6X120+3X97TALCHER HVDC 2X80

RENGALI 31.5* * TERTIARYJEYPORE 31.5* + WINDING OF

1 x 63 400/220KV ICTs List of Series Compensation devices and HVDC converters 1 FSC + TCSC AT PURNEA END OF 400KV PURNEA - MUZAFFARPUR I & II 2 FSC AT JEYPORE END OF 400KV MERAMUNDALI-JEYPORE LINE 3 FSC AT JEYPORE END OF 400KV JEYPORE - GAJUWAKA I& II 4 500MW HVDC BACK-TO-BACK CONVERTER AT SASARAM


ERLDC:POWERGRID

Annexure XVI.. contd List of Important Generators


List of Important GeneratorsControl Area Station Type Owner Capacity (MW)

Farakka Farakka STPS ISGS Thermal NTPC 3x200+2x500Kahalgaon Kahalgaon STPS Stage I ISGS Thermal NTPC 4x210

Kahalgaon STPS Stage II ISGS Thermal NTPC 2x500Talcher Stg 1 Talcher STPS Stage I ISGS Thermal NTPC 2x500Talcher Stg II Talcher STPS Stage II ISGS Thermal NTPC 4x500Teesta Teesta ISGS Hydro NHPC 3x170Rangeet Rangeet ISGS Hydro NHPC 2x20Bhutan Tala ISGS Hydro DGPC(Bhutan) 6x170Bhutan Chukha ISGS Hydro DGPC(Bhutan) 4x84Bhutan Kurichu ISGS Hydro DGPC(Bhutan) 4x15

Jharkhand Tenughat Thermal TVNL(JSEB) 2x210

DVC Waria Thermal DVC 1x210Mejia Thermal DVC 4x210+2x250Bokaro Thermal DVC 3x210

West Bengal Kolaghat Thermal WBPDCL 6x210Sagardighi Thermal WBPDCL 2x300Bakreswar Thermal WBPDCL 4x210Santaldih Thermal WBPDCL 1x250PPSP Hydo WBPDCL 4x225DPL Thermal DPL 1x300Budge-Budge Thermal CESC 2x500

Orissa IB Thermal OPGC 2x210Balimela Hydro OHPC 6x60+2x75U-Kolab Hydro OHPC 4x80U-Indravati Hydro OHPC 4x150Rengali Hydro OHPC 4x50

ERLDC:POWERGRID

Annexure XVII : Automatic UFR load shedding Schemes System Stage- I

(48.5Hz Inst) Stage-II

(48.2 Hz Inst) Stage –III

(48.0 Hz Inst) BSEB 30 MW 36 MW 43 MW JSEB 17 MW 12 MW 22 MW DVC 56 MW 55 MW 76 MW OPTCL 77 MW 77 MW 105 MW WBSETCL (including CESC)

120 MW 120 MW 164 MW

Total 300 MW 300 MW 410 MW


ERLDC:POWERGRID

Annexure XVIII: Power Demand Over ride PDOs at Talcher

Sl No Number of Connected generators /AC lines

DC Power Limit in MW

1 6 No Limit 2 5 No Limit 3 4 No Limit 4 3 1500 MW 5 2 1000 MW 6 1 500 MW 7 0 Controlled Shut down /ESOF

PDOs at Kolar Sl No Number of Connected generators /AC

lines DC Power Limit in MW

1 6 No Limit 2 5 2000 MW 3 4 1500 MW 4 3 1000 MW 5 2 500 MW 6 1 Controlled Shut down 7 0 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 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

500 MW

3 PDO-5 East Bus frequency at 49.0 Hz and below. Rate of fall of frequency df/dt – 0.3 Hz./sec

150 MW

4 PDO-6 Overload Trip contact of Gajuwaka S/s ICT on southern side

250MW

ERLDC:POWERGRID

Annexure : XIX :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


ERLDC:POWERGRID

CASE -2( Logic for one pole blocking with ground mode)


CASE-1 (Logic for 2-pole blocking)

• Sum Total of Power through 4 AC feeders before disturbance =P

&P>1450MW

BOTH POLE TRIPTrip Unit#6&

P>1450MW

BOTH POLE TRIPTrip Unit#6

&For 1150MW>P>1000MW

BOTH POLE TRIP

Ramp down U#5 by 150 MW or trip Unit #5


BOTH POLE TRIP

Ramp down U#5 by 150 MW or trip Unit #5


BOTH POLE TRIP

Ramp down U#6, U#5, U#4 by 150 MW each. or trip Unit #5


BOTH POLE TRIP



BOTH POLE TRIP

Ramp down U#4, U#5 by 150 MW each. or trip Unit #5


BOTH POLE TRIP


t

t

t

• Sum Total of Power through 4 AC feeders before disturbance =P

Sum Total of Power through 4 AC feeders after disturbance =P1

&P>1600MW

ONE POLE TRIPTrip Unit#6100<P1<180MW t&

P>1600MW

ONE POLE TRIPTrip Unit#6100<P1<180MW t

&1600MW>P>1450MW

ONE POLE TRIP


100<P1<180MW t&1600MW>P>1450MW

ONE POLE TRIP


100<P1<180MW t

&1450MW>P>1300MW

ONE POLE TRIP


100<P1<180MW t&1450MW>P>1300MW

ONE POLE TRIP


100<P1<180MW t

&1300MW>P>1150MW

ONE POLE TRIP

Ramp down U#5 by 150 MW each. or trip Unit #5100<P1<180MW t&

1300MW>P>1150MW

ONE POLE TRIP

Ramp down U#5 by 150 MW each. or trip Unit #5100<P1<180MW t

ERLDC:POWERGRID

Annexure XX: 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

Low Frequency( 47.0Hz)

CESC The entire system gets islanded at Howrah ( the synchronising point)

Low frequency (47.8 Hz)

NALCO(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

Low Freq( 47.4 Hz)

ICCL(CPP within Orissa system)

The plant gets connected to OPTCL network at 132kV . The 132/33 kV Transformer gets isolated from 132kV system

Low Freq ( 47.5 Hz)

RSP (CPP in Orissa 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

Low frequency(Both the schemes operate at 47.6 Hz)


ERLDC:POWERGRID

Annexure XXI : Scheduling Formats ( Broad guidelines for the Formats) Form A: 1. DC Declaration by ISGS Thermal For Date: Time Block Station 1 Ex(PP) DC MW Station 2 Ex(PP) DC MW Station N Ex(PP)DC MW 1 2 3 . . . . . 96 2. Technical Minimum Limit (MW) upto which station can be backed down without restoring to oil support 3. Ramp up Rate MW/min or steps of load raising in avg MW 4. Ramp Down Rate MW/min steps of load lowering in Avg MW 5. Remarks : Unit under Maintenance/Overhauling/Other constarints Form A for ISGS Hydro

_O

C AP AC IT Y D E C L A R AT IO N (E X -B U S )


F O R D ATE

R E V . N o . D AT E O F IS S U E T IM E

(A ) U N IT N o s .C A P A B IL IT Y E x-

B U S (M W )

123

( ii)

( iii)

F R O M T O0 0 :0 0 2 4 :00 :0 0

(v )

F rom (h h :m m ) T o (hh :m m )

00 :00 24 :0 0

D C (E ) (M W H ) R E V N O M S G N O

(v ii) M W

(v iii) M W

(ix ) %

(B )( i) m tr.

( ii) C u m ecs

( iii)_ C u m ecs

( iv )G en e ra tio n

(M W )

(v i)

(v ii)

0 :00 T O 2 4 :0 00 :00 T O 2 4 :0 00 :00 T O 2 4 :0 0

D E C L A R E D C A P A B IL IT Y T IM E (h h :m m )

D E C L A R E D C A P A B IL IT Y O F E XB U S (M W )

U n its to go u n d er p la n ne d s h u td o w n du r in g n e xt da y N IL

U n its lik e ly to re tu rn fro m p la n n e d s h u tdo w n d u ring ne xt da y N IL

S U G G E S T E D S C H E D U L E

D C E x-b us (M W )

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

T IM E D U R A T IO ND ec la re d c a p a b ility b a se d o n A -(i), (ii) & (iii) ab o ve ( iv )

C ap a b ility a t 00 :0 0 H rs . o f ne xt da y( i)

A c tu a l E x- bu 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 sc he d u le

(A -E ) (M W H )

(v i)

D ec la re d C a pa c ity ( T h e m a xim u m M W a v a ila b le fo r 3 h rs . o r m ore D u rin g p ea k in g )

E x- B u s M W HN H P C D AT A F O R T H E D AT E

T IM E (h h :m m )T im e d u ra tion fo r w h ic h m a xim u m g e n era tio n ca n b e su s ta in e d a t a s tre tch (D ep e n d ing U p o n A n tic ip a te d in flo w )

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 de r n o rm a l vo ltag e a nd fre q ue n c yC ap a c ity In d e x [(v ii) / (v iii)*10 0 ]R E S E R V O IR L E V E L AN D IN F L O W S S T AT U SR es e rvo ir leve l (C u rre n t)A ve ra g e In flo w s o n p re v io u s da y

(v )

M in im um 'm u s t ru n ' g en e ra tio n ( if a n y) a lo n g w ith tim e pe riod

R E M A R K S :-

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 S G . N O .

A n y o th e r c on s tra in ts

A n tic ip a te d ave ra g e in flo w s fo r th e n e xt d a yO ve rloa d C a p a c ity

S H IF T IN C H A R G E

T O : S C E , E R L D C , K O L K AT A

ERLDC:POWERGRID

Form B Statement of Entitlement for beneficiaries Constituent : For Date Time Block DC Fig : in MW Form C: Statement of Requisitions from Beneficiaries For Date:

__Op

Time Ex(PP) DC Declared by ISGSs Ex(PP) Entitlement fromBlock Stn 1 Stn 2 . . Stn N Stn 1 Stn 2 . . Stn N

123

96

Time Ex(PP) Requisitions from ISGSs Bilaterals & PXs

_______________________________________________________________________ erating Procedures for Eastern Region Page 99 15-12-2008

Block Stn 1 Stn 2 . . Stn N Utility 1 Utility 2 . . Stn N123

96Figure in MW

ERLDC:POWERGRID

Form D : Format for Schedule of drawal by Constituents For Date F

_O

Stn 1 Stn 2 . . Stn N LOSS DEBIT BILAT IEX PXI NET EX-PP EX-PP EX-PP EX-PP EX-PP FOR TOTAL TOT. TOT. DRAWAL

ormat for Schedule of Ex PP Generation For Date:

Tm Pt. Blk ISGS SCHD.WHEEL

12..

....

96

AVL SCHD AVL SCHD AVL SCHD AVL SCHD AVL SCHD Un Req Un Req


StN 1 Stn 1 Stn 2 Stn2 . . . . Stn N Stn N Surplus Stn 1 Surplus Stn NTm Pt. Blk (Ex-PP) (Ex-PP) . . . . ( Ex-PP ) ( Ex-PP ) ( Ex-Bhu ) ( Ex-Bhu ) ( Ex-PP ) ( Ex-PP )

12 96

ERLDC:POWERGRID

Annexure :XXII

B’SARIFF

SASARAM(E)

B

S

E

B

J S E B

C.

SECTOR

ER

N E R

D

V

C

SR

BHUTAN GALEGPHU

BONGAIGAON

SALAKATI BIRPARA

NE84

NE83

NE85

NE86/

NE81

NE82 ER 43ER 42

ER 01BI 01

ER 02BI 02

PURNIAPURNIA

ER 62BI 03 ER 63BI 04

K’GAON

K’GAON K’GAON

SABOUR BI 07

BI 10

KH 13

KH 19

DC-01

DC-02

GAJUWAKA GAJUWAKA(S)

ER 06

ER 05 DV 01

DV 03

ER 12

ER 11

KALYANESWARIMAITHON

PARULIA PARULIA

BINAGURI

(M) (C)

(C) (M)

(M)(C)

(C)

(C)

(C)

(C)

(C)

(M)

(M)

(M)

(M)

(M)

METER LOCATIONS IN C. SECTOR INTER-CONNECTED SYSTEM

ER 21

ER 87

NR

ER 83

ER 82

WRER-8 0

ER-8 1

ROURKELA RAIGARH(M) (C)

B’SARIFF

(M)

NR-09 NR-10

(M)

CS-57

CS-58

ER 48

ER 03BI 67

DEHRI (C) (M) PUSAULI

BI 62 ER 55

KHAGAUL (C) ARRAH(M) BI 13 BI 14

ARRAH (C) ARRAHBI 11

BI 12

DUMRAO (C) ARRAH

ER 09

ER 10 (M)

(M)

BI 62 ER 78

K,NASA PUSAULIER 79

SASARAM(N)(C)

DEHRI (C)

DC-03

DC-04

ER-56 NR-03PUSAULI SAHUPURI

400 KV 220 KV 132 KV (M) ---- MAIN (C) ----- CHECK

FARAKKALALMATIA

K’GAON LALMATIA FK 14 JS 04

JS 03 KH 14

(C) (M)

(M)(C)

JS 01 ER 17

JS 02

R’CHANDRAPUR JAM’PUR

ER 18

(C)(M)

HATIA (C) RANCHI(M)EM 44

CHANDIL (C) RANCHI(M)EM 45

BI 68 EM 31KANTI (M) MUZ’PUR (C)

BI 69 EM 32

KHAGAUL (C) (M) PATNA

FATUAH (C) (M) PATNA

MUZ’PUR GORKH’PUR(M) (C) EM-25 NR-11

EM-26 NR-12

PATNA BALIA(M) (C) EM-57 NR-01

EM-53 NR-02

(M)(C)

B’CHARIF BALIA(M) (C) EM-21 NR-13

EM-22 NR-14

EM 72

EM 73


ERLDC:POWERGRID

G

R I

D

C

O

C.

SECTOR

ER

W

B

S

E

TC

L

ER 23 OR 01

ER 24 OR 02

OR 9

TL 12

TL 11

OR 10

TARKERA

TSTPPMERAMUNDALI

ROURKELA

TL 10 OR 11

TL 09 OR 12

OR 04

OR03 ER 31

ER 30

ER 34

ER 35

OR 05

OR 06

ER 86OR 13

TALCHER TPS TSTPP

JEYPORE

INDRAVATIINDRAVATI

TSTPP

RENGALI RENGALI

JAYNAGAR

RENGALI PH

WB 11 RG 06

BARIPADA KOLAGHAT

ER 27 WB 10

RANGIT RAMAM

WB 08FK 15

FK 16

JEERATFARAKKA

WB 05

WB 06

WB 07

ER 58ER 59

ER 07

MALDA MALDA

PARULIA B’NAGAR

(C) (M)

(C)

(C)

(C)

(C)

(C)

(C)

(C)

(C)

(C)

(C)

WB 02 EM 75

NJP NBU

BIRPARA BIRPARA

WB 03

WB 04ER 52

ER 53

(C)

(C)

(M)

(M)

(M)

(M)

(M)

(M)

(M)

(M)

(M)

(M)

(M)

(M)

NJPBINAGURI (M)ER 19

SI KKI

M

RG 07 SM 01RANGIT MELLI(M) (C)

BARIPADABARIPADA

BARIPADAR’RANGPUR

RG 10

MERAMUNDALI TSTPP(M)(C) TL 27

TL 28

OR 07

OR 08

ER 99

ER 98

ER 38OR 14

MERAMUNDALI JEYPORE

66kV


MELLI

NJP MELLI

GANGTOK SM 02

SM 03

EM 04EM 03

EM 05 EM 06GANGTOK

132/66kV

RANGIT MELLI(M) (C)

FARAKKA (C) SAGARDIGHI

SUBHASGRAM JEERAT(M) (C)EM 17 WB 09SUBHASGRAM JEERAT(C) (M)

EM 18 L’KANTIPUR

EM 19

(C) (M)

ER 45

BALASORE BARIPADA(C) (M)OR 60 EM 58

EM 66

(M) WB 12

SAGARDIGHISUBHASGRAM (M)

EM 74 WB 13

(C)

ER 44

PARULIA PPSP

BALASORE BARIPADA


ERLDC:POWERGRID

B’SARIFF B’SARIFF

N R

CENTRAL

SECTOR

B

S

E

B

RAJGIRBARHI

PURNIA PURNIA

K’GAON K’GAON

K’GAONSABOUR

CHANDAULI KARMNASA

SONENAGAR

BI 66

BI 63

ER 01

BI 57 JS 62

BI 01

ER 02 BI 02

BI 10 KH 19

ER 62 BI 03

ER 63 BI 04

BI 07 KH 13BI 55DV 51

RIHAND


(M) (C)

(M) (C)

(C) (M)

(M) (C)

(C) (M) (C) (M)

(M)

J

S

E

B

BODHGAYA PATRATU

B’SF TENUGHAT

LALMATIA SABOUR

SULTANGANJ

SONENAGAR

DEOGARH SULTANGANJ

GARWA BI 60 JS 64

BI 58

BI 59

JS 63

BI 61 JS 65

BI 54

BI 53

JS 61

JS 60

BI 52 JS 59

(M) (C)

(M)

(M)

(M)

(M)

(M)

(M)

(C)

(C)

(C)

(C)

(C)

SAHUPURI (C) NR 06

NR 05

METER LOCATIONS IN BSEB INTER-CONNECTED SYSTEM

ER 48

BI 67 ER 03

ARRAH (C) ARRAH

BI 11

BI 12

DUMRAO (C) ARRAH

ER 09

ER 10 (M)

(M)

KHAGAUL (C) ARRAH(M) BI 13

BI 14

DEHRI (C) (M) PUSAULI

BI 62 ER 55 NR 07 ER 78

PUSAULIK’NASA

DEHRI (C)

KARMNASA (M)

BI 68 EM 31KANTI (M) MUZ’PUR (C)

BI 69 EM 32

KHAGAUL (C) (M) PATNA

FATUAH (C) (M) PATNA

ER 79

EM 72

EM 73


ERLDC:POWERGRID

G R I D C O

B

S

E

B

NR

CENTRAL

SECTOR

J

S

E

B

GOELKERAROURKELA

KENDPOSI JODA

RAMCHANDRAPUR JODA

WB SEB

SANTALDIH CHANDIL

D

V

C

PATRATU

BODHGAYA PATRATU

B’SF TENUGHAT

PATRATU

JAMTARA MAITHON

CHANDIL MANIQUE

FARAKKA LALMATIA

K’GAONLALMATIA

SONENAGAR GARWA

DEOGARHSULTANGANJ

GARWAJS 58

JS 01 ER 17

JS 02 ER 18

FK 14 JS 04

JS 03 KH 14

WB 53

JS 59

JS 60 BI 53

BI 52

JS 61 BI 54

JS 62 BI 57

BI 58 JS 63

JS 64 BI 60

JS 65 BI 61

JS 57

JS 66 DV 56

JS 54

JS 55

JS 56

JS 51

JS 52 /

JS 53

DV 53

DV 55

OR 53

OR 52

OR 51

RIHAND

R’CHANDRAPUR

R’CHANDRAPUR JAM’PUR


BC

(C)

(M)

(M)

(M) (C)

(M)

(M)

(M)

(M) (C)

(M) (C)

(M) (C)

(M)

(M)

(C)

(C)

(C) (M)

JAM’PUR(C)

SABOUR LALMATIA

SULTANGANJ BI 59

(C) (M)

(C) (M)

(C) (M)

(C)

(M) (C)

(M) (C)

METER LOCATIONS IN JSEB INTER-CONNECTED SYSTEM

FARAKKALALMATIA

K’GAON LALMATIA FK 14 JS 04

JS 03 KH 14

(C) (M)

(M) (C)

HATIA (C) RANCHI(M) EM 44

CHANDIL (C) RANCHI(M) EM 45


ERLDC:POWERGRID

W

B

S

E

B

B S E B

J S E B

D

V

C

G R I D C O

JAMSHEDPURJODA

KH’PUR KHARAGPUR

DPL WARIA

WARIABIDHANNAGAR

PURULIA PURULIA

DV 53

JS 55

JS 54

JS 56

JS 66

BC

DV 55

BI 56

BI 55 DV 51

DV 56

ER 06

ER 05 DV 01

DV 03

ER 12

ER 11

KOLAGHAT KOLAGHAT DV 62

DV 61

DV 60 WB 51

DV 65

DV 58

DV 57

WB 60

OR 54

PATRATUPATRATU

RAJGIR

BSF

BARHI

BARHI

JAMTARA MAITHON

CHANDIL MANIQUE

PARULIA


(M)

(M)

(M)

(C) (M)

(C) (M)

(C)

(M)(C)

(M)

(M)

(M)

(M)(C)

(M)

(C)

(C)

(M)

(M

WB 54 DV 64


ERLDC:POWERGRID


CENTRAL

SECTOR

C S E B

D V C

G

R I

D

C

O

J S E B

GOELKERA

RAIGARH

KORBA

BUDHIPADAR

ROURKELA

KENDPOSI

RAMCHANDRAPUR JODA

OR 55

JODA

JODA

OR 53

OR 52

JS 51

JS 52

JS 53 OR 51

BC

DV 57

ER 23 OR 01

ER 24 OR 02

OR 9

TL 12

TL 11

OR 10

OR 54

TL 10 OR 11

TL 09 OR 12

OR 04

OR 03

ER 31

ER 30

ER 34

ER 35

OR 05

OR 06

OR 56

OR 59

OR 57

JAMSHEDPUR JODA

TARKERA

TALCHER TPS TSTPP

JEYPORE

TSTPP

TSTPP

RENGALIRENGALI

JAYANAGAR

RENGALI PH

MERAMUNDALI

ROURKELA

400 KV 220 KV 132 KV (M) ---- MAIN (C) ---- CHECK

(M) (C)

(M)

(M) (C)

(C)

(M)

(M)

(C) (C)

(M) (C)

(C)

(M) (C)

(M) (M) (C) (C)

(C)

(M)

(M)

(C)

(C) OR 13 ER 86

INDRAVATI INDRAVATI

CS 56

CS 54

KORBA (C) CS 55

(M)

BARIPADABALASORE

BARIPADABARIPADA

BARIPADAR’RANGPUR

TSTPPMERAMUNDALI

TSTPPMERAMUNDALI

OR 14 ER-38 JEYPOREMERAMUNDALI (M) (C)

TL 27

TL 28

OR 07

OR 08

ER 98

ER 99

BUDHIPADAR

BUDHIPADAR

(M) (C)

(M) (C)

(M) (C)

OR 60

OR 61

OR 62

ERLDC:POWERGRID

W

B S

E

T

C L

CENTRAL

SECTOR

J S E B

SANTALDIHCHANDIL

S I K K I

M

KALINGPONGMELLI

WB 59 SM 51 66 KV

WB 53 JS 57

DV 62

DV 61

WB 01

WB 03

WB 04

WB 05

WB 06

WB 07

WB 08

WB 11 RG 06

WB 54

ER 44

ER 52

ER 53

ER 58

ER 59

ER 07

FK 15

BARIPADAKOLAGHATER 27WB 10

DV 64

DV 65

WB 60DV 58

D

V

C KHARAGPUR KHARAGPUR

WARIA BIDHANNAGAR

KOLAGHAT KOLAGHAT

PURULIAPURULIA

MALDA

JEERAT

RANGIT RAMAM

FARAKKA

MALDA

PARULIAB’NAGAR

NJPNBU

BIRPARABIRPARA

400 KV 220 KV 132 KV (M) ----- MAIN (C) ----- CHECK

DPWARIA

METER LOCATIONS IN WBSEB INTER-CONNECTED SYSTEM

(M) (C)

(M) (C) (C) (M)

(M)(C)

(M)

(M)

(M)

(M)

(M)

(M)

(M)

(C)

(C)

(M)

(C)

(M)

(C)

(C)

(C)

(M)

(C)

BINAGURI(M) NJP

ER 19

WB 51 DV 60 WARIA BIDHANNAGAR (M) (C) SUBHASGRAM JEERAT (M) (C)

EM 17 WB 09SUBHASGRAMJEERAT (C) (M)

EM 18 L’KANTIPUR

EM 19 (M) (C)

ER 45

SUBHASGRAM

FARAKKASAGARDIGHI

SAGARDIGHI

(M)

(M) (C)

FK 16

EM 74 WB 13

WB 12

WB 02 EM 75

(C)


ERLDC:POWERGRID

S I

K

K I

CENTRAL

SECTOR

RANGITMELLI

SM 04

RG 07(M) (C)

RG 10

66 kV

132 kV

W B S E B

KALINGPONGMELLI

WB 59 SM 51 66 KV

(M) (C)

METER LOCATIONS IN SIKKIM INTER-CONNECTED SYSTEM


MELLI (C) RANGIT(M)

MELLI NJP

MELLI GANGTOK

GANGTOK

132/66 kV

EM 04

EM 06

EM 03

EM 05

SM 02

SM 03

SM 01


ERLDC:POWERGRID

ER 03

ER 60

ER 61

LALMATIA

ER 41

ER 42

MALDA

ER 44

ER 46 ER 47

ER 43

ER 40 ER 39

ER 59 ER 58

KAHALGAON(B)

BIR.(W)

BIRPARA

MALDA(W)

KH 07

KH 08

KH 13

KH 09

ER 02 ER 01

KH 12 KH 11

KH 16

KH 19

KH 15

KH 06 KH 05

KH 10

KH04 KH 03 KH 02 KH 01 KH 14 KH 18KH 17

BS 09

BSF

B’SHARIFF(BSEB)

KAHALGAON

SABOUR

CU02CU 03

CU 07 CU 08 CU06 CU05

CU 01 SINGHIGAON

METER LOCATIONS IN CENTRAL SECTOR TRANSMISSION SYSTEM

SARNATH

ER 89/2374A ER 90/2375A

ER 82ER 83

BINAGURI

SASARAM (N)

SASARAM (E)

ALLAHABAD

ARRAH

SAHUPURI

ER 88 ER 14 ER 13 ER 56

EM 39

ER 23

MAITHON

ER 33

SALAKATI

ARRAH DUMRAO

ER 10 ER 9 BI 13 BI 14

KH 32 KH 31

ER 55DEHRI

KARMANASA ER 79

DEHRI ER 78

NE 86 NE 85

ER 37

BONGAIGAON

RAMAM

RG 04

MELLI

RANGIT

RG03

RG 09RG06

RG08

RG02 RG 01

ER 51 ER50

ER76

ER52 ER 53

SILIGURI

ER54

NBU

GANGTOK RG 07

66 kV

PART-I

FARAKKA

ER 64 415A

ER 65389A

ER 63 ER 62 411A

PUR(B)

PURNEA

ER 49 415A

ER 09 / 4153A

DALKHOLA

BINAGURI

NJP (WBSEB)

MUZAFFARPUR

NR

RG10 RG11

EM02

EM01

FATUA KH 35 KH 36

EM 54 EM 55

EM 56

BALIA

PATNA EM 53 EM 57

NR 02

NR 01

SM031

SM041

KANTI (BS)

EM25 EM26 EM27 EM28

EM 7 EM 8 EM 10

EM 9

EM38 EM37 EM36 EM33

EM40

EM34 EM35

ER 22

EM23 EM24 EM29 EM30

TALA

EM 06 EM 04

EM 05 EM 03

KHAGAUL

TEESTA


ERLDC:POWERGRID

FARAKKA FK 09 FK17FK 08

FK 11 FK 10

FK 01

FK12

FK14 559A

FK 13

FK15

FK 05 FK 04 FK 03 FK 02

FK 16

FK 18 FK 07 FK 06

TIE TRA

ER70 ER69

ER 67 ER 66

ER 06

ER 23

ER 72 ER 71

ER 24

ER 05

ER 11 ER 12

ER 08

ER 25

ER 28 / 600A / 1000

ER29 469A

ER 84

SR

SR

ER 85

ER 36

ER75

ER 35 ER 34

TL06 TL08

TL 02 TL 01

TL07 TL05

ER 31

WB 10/476A

ER 74/556A

ER 30

ER 73

K’SWARI

MAITHON

PARULIA

JAMSHEDPUR

ROURKELA

TARKERA

MERAMUNDALI

TTPS

TALCHER STPP

JEERAT

KOLAGHAT

RENGALI(G)

RENGALI

RENGALI PS

JEYPORE

JEYNAGAR

ER16 ER 15

ER 07

ER 86

DURGAPUR

BIDHAN’NGR

TL 09 INDRAVATI PG

INDRAVATI PG

ER 17

BS1 05 BS 06

ER18

TL 04 TL 10

TL 13 TL 12

TL 03

400 KV 220 KV 132 KV

ER77

ER 26

RAIGARH

ER 80 ER 81

GAJUWAKA(S)

GAJUWAKA(E)

DC-3

DC-4

KAHALGAON

BARIPADA

BALASORE(GR)

BARIPADA(GR)

RAIRANGPUR(GR

ER 27

TL 11

TL 27 TL 28

TL 38

PART-II

EM 46 EM 41 EM 42RANCHI

EM 43

HATIA CHANDIL

EM 44 EM 45

MALDA KAHALGAON

WB 08/397A

EM 74

SUBHASGRAM

EM 17

WB 09

LAKH’PUR

EM 15 EM 16

EM 19

EM 18

SAGARDIGHI

WB 13

WB 12

PPSP

BANTALA


ERLDC:POWERGRID

Annexure :XXIII: Grid Maps


ERLDC:POWERGRID


ERLDC:POWERGRID

Annexure XXIV: SCHEDULE OF TRANSMISSION ASSETS OF EASTERN REGIONAL GRID (in compliance with clause 4.15 of IEGC) LINES

SL LINE OWNED BY LENGTH COND. VOLTS NO.OFNO END-1 END-2 (KM) (TYPE) (KV) CKTS.

1 FARAKKA-JEERAT POWERGRID POWERGRID WBSETCL 238 TW.MOOSE 400 12 FARAKKA-SAGARDIGHI POWERGRID NTPC WBPDCL 67 TW.MOOSE 400 13 JEERAT-SUBHASGRAM POWERGRID WBSETCL POWERGRID 80 TW.MOOSE 400 14 JEYPORE-MERAMUNDALI POWERGRID POWERGRID(ER) OPTCL 456 TW.MOOSE 400 15 TSTPP-MERAMUNDALI POWERGRID NTPC OPTCL 51 TW.MOOSE 400 26 JEYPORE - INDRAVATI POWERGRID POWERGRID POWERGRID 72 TW. MOOSE 400 17 INDRAVATI - RENGALI POWERGRID POWERGRID POWERGRID 356 TW. MOOSE 400 18 FARAKKA - KAHALGAON POWERGRID NTPC NTPC 95 TW. MOOSE 400 29 SAGARDIGHI -SUBHASGRAM POWERGRID POWERGRID POWERGRID 256.3 TW. MOOSE 400 1

10 PARULIA - JAMSHEDPUR POWERGRID POWERGRID POWERGRID 177 TW. MOOSE 400 111 MAITHON - JAMSHEDPUR POWERGRID POWERGRID POWERGRID 153 TW. MOOSE 400 212 MAITHON - KAHALGAON POWERGRID POWERGRID POWERGRID 172 TW. MOOSE 400 213 MAITHON - RANCHI POWERGRID POWERGRID POWERGRID 200 TW. MOOSE 400 214 FARAKKA - MALDA POWERGRID NTPC POWERGRID 40 TW. MOOSE 400 215 KAHALGAON BIHARSARIFF I & II POWERGRID NTPC POWERGRID 201 TW. MOOSE 400 216 KAHALGAON-BIHARSARIFF III & IV POWERGRID NTPC POWERGRID 166 TW. MOOSE 400 217 KAHALGAON -PATNA POWERGRID NTPC POWERGRID 257 QD. MOOSE 400 218 TSTPP - ROURKELA POWERGRID NTPC POWERGRID 171 TW. MOOSE 400 219 FARAKKA - PARULIA POWERGRID NTPC POWERGRID 150 TW. MOOSE 400 120 TSTPP - RENGALI POWERGRID NTPC POWERGRID 24 TW. MOOSE 400 221 JAMSHEDPUR - ROURKELA POWERGRID POWERGRID POWERGRID 174 TW. MOOSE 400 222 MALDA - PURNEA POWERGRID POWERGRID POWERGRID 167 TW. MOOSE 400 223 PURNEA - BINAGURI I & II POWERGRID POWERGRID POWERGRID 168 TW. MOOSE 400 224 PURNEA - BINAGURI III & IV POWERGRID POWERGRID POWERGRID 160 QD. MOOSE 400 225 PURNEA - MUZAFFARPUR POWERLINKS POWERGRID POWERGRID 240 QD. MOOSE 400 226 BIHARSHARIFF-MUZAFFARPUR POWERGRID POWERGRID POWERGRID 130 TW. MOOSE 400 227 BIHARSHARIFF- PUSAULI POWERGRID POWERGRID POWERGRID 195 TW. MOOSE 400 228 TALA - BINAGURI I & II (Indian part POWERGRID THEP POWERGRID 115 TW. MOOSE 400 229 TALA - BINAGURI IV (Indian part) POWERGRID THEP POWERGRID 98 TW. MOOSE 400 130 MALBASE-BINAGURI (Indian part) POWERGRID BPC POWERGRID 125.1 TW. MOOSE 400 131 BINAGURI-BONGAIGAON POWERGRID POWERGRID(ER) POWERGRID(NER) 216 TW.MOOSE 400 232 JEYPORE-GAZUWAKA POWERGRID POWERGRID(ER) POWERGRID(SR) 220 TW.MOOSE 400 233 MUZZFARPUR-GORAKHPUR POWERLINKS POWERGRID(ER) POWERGRID(NR) 261 QUAD-MOOSE 400 234 PATNA-BALIA POWERGRID POWERGRID(ER) POWERGRID(NR) 195 QUAD-MOOSE 400 235 BIHARSHARIFF-BALIA POWERGRID POWERGRID(ER) POWERGRID(NR) 242 QUAD-MOOSE 400 236 ROURKELA-RAIGARH POWERGRID POWERGRID(ER) POWERGRID(WR) 212 TW.MOOSE 400 237 TEESTA-V - BINAGURI POWERGRID NHPC POWERGRID 115 TW. MOOSE 400 238 ARRAHA-KAHAGAUL POWERGRID POWERGRID BSEB 50 ZEBRA 220 239 FARAKKA-LALMATIA POWERGRID NTPC JSEB 79 ZEBRA 220 140 BINAGURI-NJP POWERGRID POWERGRID WBSETCL 0.2 ZEBRA 220 241 BIRPARA- CHUKHA (Indian part) POWERGRID POWERGRID POWERGRID 76 ZEBRA 220 242 BIRPARA-MALBASE (Indian part) POWERGRID POWERGRID POWERGRID 40 ZEBRA 220 143 BIRPARA-SALAKATI POWERGRID POWERGRID(ER) POWERGRID(NER) 160 ZEBRA 220 244 DALKHOLA-PURNEA POWERGRID POWERGRID POWERGRID 41 ZEBRA 220 245 BIRPARA-BINAGURI POWERGRID POWERGRID POWERGRID 80 ZEBRA 220 246 NJP-BINAGURI POWERGRID POWERGRID POWERGRID 6 ZEBRA 220 247 NJP-DALKHOLA POWERGRID POWERGRID POWERGRID 119 ZEBRA 220 248 DALKHOLA-MALDA POWERGRID POWERGRID POWERGRID 116 ZEBRA 220 249 SASARAM-ARRAH POWERGRID POWERGRID POWERGRID 112 ZEBRA 220 250 MUZZFARPUR-KANTI POWERLINKS POWERGRID BSEB 22 ZEBRA 220 251 PUSUALI-SAHUPURI BSEB & UPPCL POWERGRID UPPCL 72 ZEBRA 220 152 BUDHIPADAR-RAIGARH POWERGRID OPTCL CHATTISGARH 81 ZEBRA 220 153 KAHALGAON-KAHALGAON POWERGRID BSEB NTPC 2 PANTHER 132 154 DEHRI--PUSUALI POWERGRID BSEB POWERGRID 63 PANTHER 132 155 KARMANASA--PUSUALI POWERGRID BSEB POWERGRID 29 PANTHER 132 156 RANGIT-RAMMAM POWERGRID NHPC WBSETCL 27 PANTHER 132 157 KAHALGAON-SABOUR POWERGRID NTPC BSEB 37 PANTHER 132 158 KAHALGAON-LALMATIA POWERGRID NTPC JSEB 34 PANTHER 132 159 RANGIT - MELLI POWERGRID NHPC SIKKIM 37 LARK 66 160 GANGTOK - MELLI POWERGRID POWERGRID SIKKIM 37 PANTHER 132 161 NJP-MELLI POWERGRID POWERGRID SIKKIM 90 PANTHER 132 1

CONNECTED SYSTEMS


ERLDC:POWERGRID

TRANSFORMERS

SUBSTATION VOLTAGE

RATIO CAPACITY (MVA) OWNERSHIP FARAKKA 400/220 1X315 POWERGRID

JAMSHEDPUR 400/220 2X315 POWERGRID PARULIA 400/220 2X315 POWERGRID MALDA 400/220 2X315 POWERGRID

BIHARSHARIF 400/220 3X315 POWERGRID JEYPORE 400/220 2X315 POWERGRID RENGALI 400/220 2X315 POWERGRID MAITHON 400/220 2X315 POWERGRID

ROURKELA 400/220 2X315 POWERGRID SASARAM 400/220 2X315 POWERGRID BINAGURI 400/220 2X315 POWERGRID

NEW PURNEA 400/220 2X315 POWERGRID MUZAFFARPUR 400/220 2X315 POWERGRID

BARIPADA 400/220 2X315 POWERGRID INDRAVATI 2ND 400/220 1X315 POWERGRID SUBHASGRAM 400/220 2X315 POWERGRID

PATNA 400/220 2X315 POWERGRID RANCHI 400/220 2X315 POWERGRID

TALCHER HVDC CONV. XMER 400/(210/√3)/210 6X(397/198.5/198.5) POWERGRID SSRM HVDC CONV. XFER

(EAST) 400/(93/√3)/93 3X(234/117/117) POWERGRID SSRM HVDC CONV. XFER

(NORTH) 400/(93/√3)/93 3X(234/117/117) POWERGRID BIRPARA 220/132 1x50+1x100 POWERGRID

NJP 220/132 1X100 POWERGRID PURNEA 220/132 3X100 POWERGRID MALDA 220/132 3X50 POWERGRID

BARIPADA 220/132 1X160 POWERGRID ARRAHA 220/132 2X100 POWERGRID

GANGTOK 132/66 2X50 POWERGRID

SERIES COMPENSATION ELEMENTS & HVDC CONVERTERS SL ELEMENT 1 FSC + TCSC AT PURNEA END OF 400KV PURNEA - MUZAFFARPUR I & II 2 FSC AT JEYPORE END OF 400KV MERAMUNDALI-JEYPORE LINE 3 FSC AT JEYPORE END OF 400KV JEYPORE - GAJUWAKA I& II 4 500MW HVDC BACK-TO-BACK CONVERTER AT SASARAM


ERLDC:POWERGRID

REACTORS & HARMONIC FILTERS

LENGTH REACTOR CAPACITY (MVAR)LINE/SUB-STN ( KM ) REMARKS

BUS LINE ENDFARAKKA - JEERAT-I 238 50 JEERAT

SAGARDIGHI-SUBHASGRAM 256.3 50 SUBHASHGRMPPSP-PARULIA-I 150 1X50 PARULIA

K'GAON-B'SHARIFF-I 196 1X50 B'SHARIFFK'GAON-B'SHARIFF-II 196 1X50 B'SHARIFFK'GAON-MAITHON-I 172 1X50 MAITHONK'GAON-MAITHON-II 172 1X50 MAITHON

JAMSHEDPUR-R'KELA-I 174 1X50 ROURKELA SWITCHABLEJAMSHEDPUR-R'KELA-II 174 1x50 ROURKELA

BARIPADA-RENGALI 239 1x 63 RENGALIRENGALI-INDRAVATI(S/C) 356 1x50 RENGALI

1x50 INDRAVATIMALDA-PURNEA I 167 1X63 MALDAMALDA-PURNEA II 167 1X63 MALDA

BINAGURI-BONGAIGAON-II 216 1x63 BINAGURI SWITCHABLEPURNEA-BINAGURI-II 168 1x63 PURNEA

PURNEA-MUZAFFARPUR-I 240 1x63 PURNEA SWITCHABLE1x63 MZFRPR SWITCHABLE

PURNEA-MUZAFFARPUR-II 240 1x63 PURNEA SWITCHABLE1x63 MZFRPR SWITCHABLE

ROURKELA-RAIGARH I 212.4 1x63 ROURKELAROURKELA-RAIGARH II 212.4 1X63 ROURKELA

MERAMUNDALI-JEYPORE 456 1x80 JEYPOREB'SHARIFF-SASARAM I 195 1X63 SASARAM SWITCHABLEB'SHARIFF-SASARAM II 195 1X63 SASARAM SWITCHABLESASARAM -SARNATH 76 1X63 SASARAM SWITCHABLE

SASARAM -ALLAHABAD 271 1X63 SASARAM SWITCHABLEMUZAFFARPUR-GRKPR-I 260 1X63 MUZAFFARPUR SWITCHABLEMUZAFFARPUR-GRKPR-II 260 1X63 MUZAFFARPUR SWITCHABLE

KAHALGAON-PATNA-I 257 1X50 PATNAKAHALGAON-PATNA-I 257 1X50 PATNA

RANCHI-SIPAT-II 405 1X80 RANCHIBIHARSHARIFF 1X50+1X80

MAITHON 1X50JAMSHEDPUR 2X50

ROURKELA 1X50PARULIA 1X50

BINAGURI 2X63NEW PURNEA 1X63

MUZAFFARPUR 1X63PATNA 1X80RANCHI 1X80

SASARAM (EAST) FILTER BANK 4X112SASARAM (NORTH) FILTER BANK 4X112

TALCHER FILTER BANK 6X120+3X97TALCHER HVDC 2X80

RENGALI 31.5* * TERTIARYJEYPORE 31.5* + WINDING OF

1 x 63 400/220KV ICTs


ERLDC:POWERGRID

Annexure:XXV LIST OF EXTERNAL DOCUMENTS


Sl No

Document Title Date of Issue

1 EA 2003 The Electricity Act, 2003 02.06.03 2 Indian

Electricity Grid Code

2.1 Regulation on Grid Code 14.03.06 2.2 Amendment of Regulation on Grid Code 13.12.06 2.3 Amendment of Regulation on Grid Code 17.03.06 2.4 Amendment of Regulation on Grid Code 28.08.06 2.5 Amendment of Regulation on Grid Code 18.04.07 2.6 Amendment of Indian Electricity Grid Code 11.09.08 3 CEA

Regulations

3.1 Metering Regulations 17.03.06 3.2 Technical Standards for Connectivity to the

Grid 21.02.07

3.3 Business Regulation 18.08.06 4 CERC Orders

and Regulations

4.1 CERC Terms and Conditions of Tariff

Regulation Terms and Conditions of Tariff 2004-09

26.04.04

4.1.1 Fourth-Amendment-Regulations-2007 sale of infirm power hydro scheduling UI etc Notification

28.12.07

4.1.2 Fourth Amendment Regulations 2007 Part II-Valuing Infirm Power at UI rate

07.01.08

4.1.3 Fourth Amendment Regulations 2007-Explanatory Memorandum- Infirm power and Hydro scheduling

07.01.08

4.1.4 Regulations-2007-Part-III-UI cap at Rs-4.06 and DC of Hydro stations

14.1.2008

4.1.5 Tariff-Fourth-Amendment-Regulations-2007-UI rate revision to Rs-10.

31.12.07.

4.1.6 Petition-No-53-2008 Provisional Tariff for Mejia unit 5 of DVC

30.04.08

4.1.7 Interim order on petition 85-2007 on proposed approach of sharing of charges and losses in ISTS

02.07.07

4.1.8 Pet-No-85-07 Order dtated 28.3.2008 on prposed approach on sharing of charges and losses in interstate transmission

28.03.08

4.1.9 Draft regulation on Term and conditions of 14.9.08

ERLDC:POWERGRID

Tariff-2009-14 4.2 Open Access in

Interstate Transmission

4.2.1 Regulation on OA in inter-State-Transmission- Notification

25.01.08

4.2.2 Procedure for bilateral-transaction CERC directive to CTU

31.01.08

4.2.3 Procedure for collection-transaction CERC Directive to CTU

13.06.08

4.2.4 Procedure for Scheduling of Bilateral Transaction

28.01.08

4.2.5 Procedure for scheduling of Collective Transaction

06.06.08

4.2.6 Petition-No-38-2007 Permission for setting up of POWER EXCHANGE by IEX order dated 9.6.08

09.06.08

4.2.7 Regulation on Trading margin 23.01.06 4.2.8 Regulation on Trading License 30.01.04 4.2.9 Pet-Nos-10-08-11-08-RP-No-37-08-Pet-

156-07 Open access from Nab bharat to Andhra through RETL

05.05.08

4.3 Grid Discipline and Others

4.3.1 Pet-No-54-2008-(suomotu)-UI payment default by BSEB

04.06.08

4.3.2 Petition-No-58-2008-suo-motu[1]- Control areas Demarkation of responsibilities

07.05.08

4.3.3 Pet-115-2008-Suo-motu-Maintenance of Grid discipline

16.10.08

5 Staff Papers 51 staff-papers-arranging transmission dated

17.7.08 17.07.08

5.2 Developing a common platform for electricity trading

20.07.06

5.3 Open Access in inter-state transmission 01.08.03 5.4 Pricing methodology for renewable- A

report from TERI 13.03.08

5.5 Promotion of Co generation and renewable sources of Energy

16.05.08

5.6 Remedy for default in payment of dues by Power Utilities

21.05.07

5.7 Revised scheme for incentive and disincentive Discussion Paper

14.02.08

5.8 Sharing of Interstate Transmission charges and related issues

5.9 Staff-Paper_01-09-08 restraining price of electricity through trading

01.09.08
