Reactive Power Mangament-A Resource Handbook- Jan 2012 .Pdfxhrb0978575529b486abca7eb68e0e44469xhr

N L D C R E A C T I V E P O W E R M A N A G E M E N T - a r e s o u r c e h a n d b o o k of 66 JAN-2012

POWER SYSTEM OPERATION CORPORATION LTD

Reactive Power Management – a resource handbook


INDEX

1. Introduction

2. Statutory provisions for reactive power management & voltage control

3. Reactive power & voltage control - basic concepts

4. Transmission lines and reactive power compensation

5. Series and shunt capacitors—their effect on reactive power

6. Transformer tap changer effect on reactive power

7. HVDC operation effect on reactive power

8. FACTS & reactive power control

9. Generator reactive power capability

10. Reactive power management and renewable energy

11. Ready Reckoner

12. References


ANNEXURES:

1. Inter regional transmission lines(400kV & above AC)

2. All India reactive power compensation details

3. Estimated MVAr relief available when line is opened

4. 400 & 765kV reactors installed capacity-All India level.

5. Fault level of substations.

6. Surge Impedance Loading (SIL) of transmission lines.

7. List of 765kV lines to be commissioned during 2012

8. Shunt capacitors installed capacity-All India level.

9. Series compensation and SVC –All India level

10. ICT tap position details

11. Typical transformer tap changer online/offline detail

12. List of synchronous condensers.


1. Introduction

1.1 The objective of this Reactive Power Management resource handbook is to place before the load dispatch centre personnel a handy reference document to facilitate reliable operation of the Indian power system through optimal

utilization of the available reactive power resources

1.2 Developments in power sector have seen more high voltage transmission lines at 765 kV and HVDC systems, large generating stations coming up, which makes the Indian grid more and more complex. Indian grid has interconnection with neighbouring countries also. Hence the need was felt to develop the written document for the guidance of real time operator on reactive power management for day to day operation.

1.3 No special reactive compensation devices were used in the early AC power systems, because the generators were situated close to the loads. As networks became more widespread, there was a need for development of reactive power compensation devices.

1.4 In an integrated power system, efficient management of active and reactive power flow is very important. Quality of power supply is judged from the frequency and voltage of the power supply made available to the consumers. While frequency is the measure of balance between power generated (and power available) and MW demand impinged on the system, the voltage is indicative of reactive power flows.

1.5 During the steady-state operation of an AC power system, the active power

production must match the consumption plus the losses otherwise the frequency will change. There is an equally strong relationship between the reactive power balance of a power system and the voltages

1.6 Control of voltage and reactive power should satisfy the following objectives:

a) Control the power flow in the system to an optimal level in order to reduce losses. This ensures that the transmission system operates efficiently. b) Maintain power supply quality by maintaining bus voltages close to

nominal value. c) To control the reserve reactive power in order to ensure its sufficiency

during normal and emergency conditions to prevent voltage collapse. d) System stability is enhanced to maximize utilization of the transmission

system. Voltage and reactive power control have a significant impact on system stability.

e) Maximize the existing reactive power resources to minimize investment in additional facilities.


1.7 Since reactive power cannot be transmitted over long distances, voltage control has to be effected by using special devices dispersed throughout the system.

1.8 Reactive power (VAR) is required to maintain the voltage to deliver active

power (watts) through transmission lines. Motor loads and other loads require reactive power to convert the flow of electrons into useful work. When there is not enough reactive power, the voltage sags down and it is not possible to push the power demanded by loads through the lines.

1.9 A great many loads consume not only active but also reactive power. The

electric network itself both consumes and produces reactive power. Transmission and distribution of electric power involve reactive power losses due to the series inductance of transformers, overhead lines and underground cables. The generation of power also contains reactive components. Hence it is important to monitor and control reactive power resources and reactive power consuming elements to maintain proper voltages in the grid within safe and secure limits

1.10 This document covers the basic concepts of reactive power, production and

absorption of reactive power, Methods of voltage control, Applications of Reactor, capacitor and FACTS/SVC to the transmission system, Synchronous condenser, Application of tap changing of Transformer etc.

1.11 NLDC/RLDCs shall follow up and examine reactive power absorption and

injection sources to ensure the sufficiency of reactive power absorption and injection sources in their areas in order to maintain voltage levels at all points during normal and emergency conditions. RLDCs/NLDC needs to compile the constantly updated information concerning the availability of relevant equipment.

1.12 This document is in particular focusing on reactive power management at

All India Level. Hence this document is to be read in conjunction with respective RLDC reactive power document for respective region‘s reactive power resource details.


2. Statutory provisions for reactive power management &

voltage control

2.1 PROVISION IN THE IEGC 2.1.1 As per sec 3.5 of IEGC planning criterion general philosophy:

― 3.5 Planning Criterion

General philosophy a) The planning criterion are based on the security philosophy on which the ISTS has been planned. The security philosophy may be as per the Transmission Planning Criteria and other guidelines as given by CEA. The general policy shall be as detailed below: i) As a general rule, the ISTS shall be capable of withstanding and be

secured against the following contingency outages. a) without necessitating load shedding or rescheduling of generation

during Steady State Operation: - Outage of a 132 kV D/C line or, - Outage of a 220 kV D/C line or, - Outage of a 400 kV S/C line or, - Outage of single Interconnecting Transformer, or - Outage of one pole of HVDC Bipole line, or one pole of HVDC back to back Station or - Outage of 765 kV S/C line.

b) without necessitating load shedding but could be with rescheduling of generation during steady state operation- - Outage of a 400 kV S/C line with TCSC, or - Outage of a 400kV D/C line, or - Outage of both pole of HVDC Bipole line or both poles of HVDC back to back Station or - Outage of a 765kV S/C line with series compensation.

ii) The above contingencies shall be considered assuming a pre-contingency system depletion (Planned outage) of another 220 kV D/C line or 400 kV S/C line in another corridor and not emanating from the same substation. The planning study would assume that all the Generating Units may operate within their reactive capability curves and the network voltage profile shall also be maintained within voltage limits specified.

e) CTU shall carry out planning studies for Reactive Power compensation of

ISTS including reactive power compensation requirement at the generator‘s /bulk consumer‘s switchyard and for connectivity of new generator/ bulk consumer to the ISTS in accordance with Central Electricity Regulatory Commission (Grant of Connectivity, Long-term


Access and Medium-term Open Access in inter-state Transmission and related matters) Regulations, 2009. ―

2.1.2 IEGC Section 4.6.1 Important Technical Requirements for Connectivity: ― 4.6.1 Reactive Power Compensation

a) Reactive Power compensation and/or other facilities shall be provided by STUs, and Users connected to ISTS as far as possible in the low voltage systems close to the load points thereby avoiding the need for exchange of Reactive Power to/from ISTS and to maintain ISTS voltage within the specified range.

b) The person already connected to the grid shall also provide additional reactive compensation as per the quantum and time frame decided by respective RPC in consultation with RLDC. The Users and STUs shall provide information to RPC and RLDC regarding the installation and healthiness of the reactive compensation equipment on regular basis. RPC shall regularly monitor the status in this regard. ―

2.1.3 IEGC Section 5.2 System Security Aspects ― 5.2 System Security Aspects

(s) All Users, RLDC, SLDC/STUs, CTU and NLDC shall take all possible measures to ensure that the grid voltage always remains within the following operating range.

Voltage (kV-rms)

Nominal Minimum Maximum

765 728 800

400 380 420

220 198 245

132 122 145

110 99 121

66 60 72

33 30 36

t) All Users, CTU and STUs shall provide adequate voltage control measures through voltage relay as finalized by RPC, to prevent voltage collapse and shall ensure its effective application to prevent voltage collapse/cascade tripping.

(u) Special requirements for Solar/ wind generators


(i) SLDC/RLDC may direct a wind farm to curtail its VAr drawl/injection in case the security of grid or safety of any equipment or personnel is endangered. (ii) During the wind generator start-up, the wind generator shall ensure that the reactive power drawl (inrush currents in case of induction

generators shall not affect the grid performance. ― 2.1.4 IEGC Section 5.3(g) Demand Estimation for Operational Purposes ― 5.3 Demand Estimation for Operational Purposes g) The SLDC shall take into account the Wind Energy forecasting to meet the active and reactive power requirement. ― 2.1.5 IEGC Section 6. Scheduling and Despatch Code ― 6.6 Reactive Power and Voltage Control

1) Reactive power compensation should ideally be provided locally, by

generating reactive power as close to the reactive power consumption as possible. The Regional Entities except Generating Stations are therefore expected to provide local VAr compensation/generation such that they do not draw VArs from the EHV grid, particularly under low-voltage condition. To discourage VAr drawals by Regional Entities except Generating Stations, VAr exchanges with ISTS shall be priced as follows: - The Regional Entity except Generating Stations pays for VAr drawl when voltage at the metering point is below 97% - The Regional Entity except Generating Stations gets paid for VAr return when voltage is below 97% - The Regional Entity except Generating Stations gets paid for VAr drawl when voltage is above103% The Regional Entity except Generating Stations pays for VAr return when voltage is above 103%, Provided that there shall be no charge/payment for VAr drawl/return by a Regional Entity except Generating Stations on its own line emanating directly from an ISGS.

2) The charge for VArh shall be at the rate of 10 paisa/kVArh w.e.f. 1.4.2010, and this will be applicable between the Regional Entity, except Generating Stations, and the regional pool account for VAr interchanges. This rate shall be escalated at 0.5paise/kVArh per year hereafter, unless otherwise revised by the Commission.

3) Notwithstanding the above, RLDC may direct a Regional Entity except

Generating Stations to curtail its VAr drawl/injection in case the security of grid or safety of any equipment is endangered.


4) In general, the Regional Entities except Generating Stations shall endeavor

to minimize the VAr drawl at an interchange point when the voltage at that point is below 95% of rated, and shall not return VAr when the voltage is above 105%. ICT taps at the respective drawal points may be changed to

control the VAr interchange as per a Regional Entity except Generating Station‘s request to the RLDC, but only at reasonable intervals.

5) Switching in/out of all 400 kV bus and line Reactors throughout the grid

shall be carried out as per instructions of RLDC. Tap changing on all 400/220 kV ICTs shall also be done as per RLDCs instructions only.

6) The ISGS and other generating stations connected to regional grid shall

generate/absorb reactive power as per instructions of RLDC, within capability limits of the respective generating units, that is without sacrificing on the active generation required at that time. No payments shall be made to the generating companies for such VAr generation/absorption.

7) VAr exchange directly between two Regional Entities except Generating

Stations on the interconnecting lines owned by them (singly or jointly) generally address or cause a local voltage problem, and generally do not have an impact on the voltage profile of the regional grid. Accordingly, the management/control and commercial handling of the VAr exchanges on such lines shall be as per following provisions, on case-by-case basis:

i) The two concerned Regional Entities except Generating Stations may mutually agree not to have any charge/payment for VAr exchanges between them on an interconnecting line. ii) The two concerned Regional Entities except Generating Stations may

mutually agree to adopt a payment rate/scheme for VAr exchanges between them identical to or at variance from that specified by CERC for VAr exchanges with ISTS. If the agreed scheme requires any additional metering, the same shall be arranged by the concerned Beneficiaries.

iii) In case of a disagreement between the concerned Regional Entities

except Generating Stations (e.g. one party wanting to have the charge/payment for VAr exchanges, and the other party refusing to have the scheme), the scheme as specified in Annexure-2 shall be applied. The per kVArh rate shall be as specified by CERC for VAr exchanges with ISTS.

iv) The computation and payments for such VAr exchanges shall be effected as mutually agreed between the two Beneficiaries. ―


2.2 PROVISION IN THE CENTRAL ELECTRICITY AUTHORITY (TECHNICAL STANDARD FOR CONNECTIVITY TO THE GRID) REGULATIONS 2007: Extracts from this standards is as reproduced below for ready reference.

― Part II: Grid Connectivity Standards applicable to the Generating Units The units at a generating station proposed to be connected to the grid shall comply with the following requirements besides the general connectivity conditions given in the regulations and general requirements given in part-I of the Schedule:- 1. New Generation Units

Hydro generating units having rated capacity of 50MW and above shall be capable of operating in synchronous condenser mode, where ever feasible.

2. Existing Units For thermal generating unit having rated capacity of 200 MW and above and hydro units having rated capacity of 100 MW and above, the following facilities would be provided at the time of renovation and modernization.

(1) Every generating unit shall have Automatic Voltage Regulator. Generators having rated capacity of 100 MW and above shall have Automatic Voltage Regulator with two separate with two separate channels having independent inputs and automatic changeover. ―


3. Reactive power & voltage control - Basic concepts

3.1 REACTIVE POWER 3.1.1 Reactive power is defined for AC systems only. Reactive power is produced

when the current waveform is out of phase with the voltage waveform due to inductive or capacitive loads. Current lags voltage with an inductive load and leads voltage with a capacitive load. Only the component of current in phase with voltage produces real or active power that does real work like running motors, heating etc. Current is in phase with voltage for a resistive load like an incandescent light bulb. Reactive power is necessary for producing the electric and magnetic fields in capacitors and inductors.

3.1.2 Reactive power is present when the voltage and current are not in phase, one waveform leads the other, Phase angle not equal to zero and power factor less than unity. It is measured in volt-ampere reactive (VAR). It is produced when the current waveform leads voltage waveform (Leading power factor). Vice versa, consumed when the current waveform lags voltage (lagging power factor).

Power Triangle

3.1.3 Real and reactive power is in quadrature (90 degrees out of phase) and

hence the letter Q is commonly used to designate reactive power. Real power is commonly designated as P.


3.1.4 Analogy #1 for Active Power and Reactive power is the bicycle analogy. Power stations, producing electrical energy, are represented by bikers. At the backseat of the bike there are passengers, the consumers of electrical

energy (the loads). A reactive load can be represented by a passenger leaning to one side. The fact that the passenger is leaning to one side, does not influence directly the work that the biker has to deliver, but without compensation, the bike might fall over. The biker compensates the movement of his passenger by leaning in opposite direction (= by generating reactive power).

Consequences: • A pedaling figure leaning to one side cannot work as comfortably as before i.e. limiting capacity of transmission line • The bike catches more head wind i.e. extra losses.

BICYCLE ANALOGY 3.1.5 Another analogy for understanding the Reactive power concept is the ―Beer

Mug analogy‖, a bit simplistic. Reactive power takes up space on transmission lines. Here reactive power is like the head on a beer because it takes up space in the glass leaving less room for the real beer. For a

transmission line, the square of the real power plus the square of the reactive power must be less than the square of the thermal capacity (measured in volt-amperes) of the line. When thermal capacity is exceeded significantly for a long time, the line will sag, possibly into vegetation, causing a short circuit, or anneal,. Since power is the algebraic product of voltage and current, the same power at high voltages has a lower current, and hence, has lower losses. Power Factor = Active power/Apparent power = kW/kVA

= Active power/ (Active Power2 +Reactive Power2)

= kW/ (kW2+kVAr2) = Beer/(Beer +Foam)


The more foam (higher kVAr) indicates low power factor and vice versa. 3.1.6 The additional current flow associated with reactive power can cause

increased losses and excessive voltage sags. Transmission system operators have to ensure that reactive reserves are available to handle system contingencies such as the loss of a generator or transmission line because increased current flow after the occurrence of contingencies can produce greatly increased reactive power absorption in transmission lines.

3.1.7 The transmission lines generate VARS under No load or less loaded

conditions and consume VARS under loaded conditions. At any given point of time the power system can experience different voltage levels at various locations.

3.1.8 In general, under peak load conditions, voltages are high at reactive source

points and are low at load points and the direction of reactive power flow is from source to the load, whereas, under the off peak conditions, the reactive power flow is from load points to source.

3.1.9 The transmission of VARS over transmission elements during peak load

conditions further burdens the transmission elements and as a result, the voltages at the load end become further less. Hence it is desirable to meet the reactive power requirement locally and necessary planning of reactive compensation to be carried out. Even at nominal frequency and satisfactory voltage operating conditions, voltage collapse cannot be ruled out as voltage is a local phenomenon.

3.1.10 System voltage levels are directly related to the availability of reactive

power. System events, such as the loss of a transmission line, create an instantaneous change in the reactive power demand. Shunt capacitors are not able to switch fast enough to supply the increase in demand and prevent further voltage decline. Therefore, generators must have some capability to immediately respond to system events by providing additional reactive power to the system.


3.1.11 Contrary to the active power balance, which has to be affected by means of the generators alone, a proper reactive power balance can and often has to be effected both by the generators and by dispersed special reactive devices, producing or absorbing reactive power. The reactive power sources are classified into two types, static and dynamic. The static type consists of

shunt capacitor, and shunt reactor. The dynamic type is the source of reactive power produced by generators, SVC, and OLTC.

Sources (Q- Generation) Sinks (Q – Absorption)

Static: • Shunt capacitors • Transmission Lines - charging • Under ground cables • Filter banks

Loads -Capacitive Dynamic: • Gen. Over excited • Synchronous condensers • Static Thyristor based devices (SVC)

• Loads Induction motors (pumps, fans etc) Inductive loads (chokes etc) • Transformers • Transmission lines • Static Thyristor based devices (SVC) • Reactors • Synchronous machines

Table 1- Sources and Sinks of Reactive Power 3.1.12 Static: Capacitors and inductors (or reactors) supply and consume static

reactive power, respectively. These are called static devices since they have no active control of the reactive power output in response to the system

voltage. They cannot quickly change their reactive output level with respect to system change. Dynamic: Synchronous generators, synchronous condensers, Flexible AC Transmission Systems (FACTS) including static var compensators (SVC), static compensators (STATCOM), Dynamic Var (D-var) and Super VAR are considered as dynamic reactive power devices capable of changing their output according to pre-set limits in response to the changing system voltages. Under normal operating conditions, dynamic reactive power supplies should operate with substantial reactive power reserves in order to quickly provide reactive support to the system during power system disturbances. Various sources and sinks of reactive power are given in table 1.


3.1.13 The reactive power capability from static sources is less valuable than from

dynamic sources, because dynamic sources can adjust their production or consumption of reactive power much more quickly as needed to maintain voltage and prevent a voltage collapse.


3.1.14 RLDC shall have database containing information on reactive power sources in the responsible control area. The information consists of: Reactive capability curves of generators; Synchronous condensers; Static VAR compensators;

Shunt reactor and shunt capacitors; HVDC Operation in Reactive power control. Transformer Tap changer settings; SVC & FACTS details

Static synchronous compensator (STATCOM) Other reactive power sources such as transmission lines.

3.1.15 RLDCs shall know current MVAR values, maximum and minimum MVAR absorption/injection capabilities, and operating restriction (if applicable) of each equipment so that the levels of reserve reactive power are accurate for all time. Information concerning equipment, which can significantly affect neighboring power systems, shall be available for each other.

3.2 DIFFERENT TYPE OF LOADS AND ITS REACTIVE POWER CONSUMPTION

3.2.1 A great many loads consume not only active but also reactive power. The Industry wise power factor is generally observed to be as follows:

INDUSTRY POWER FACTOR Textiles 0.65/0.75 Chemical 0.75/0.85 Machine shop 0.4 / 0.65 Arc Welding 0.35/ 0.4 Arc Furnaces 0.7 / 0.9 Coreless induction furnaces and heaters 0.15/0.4 Cement plants 0.78/0.8 Garment factories 0.35/0.6

Breweries 0.75/0.8 Steel Plants 0.6 / 0.85 Collieries 0.65/0.85 Brick Works 0.6 / 0.75 Cold Storage 0.7 / 0.8 Foundries 0.5 / 0.7 Plastic moulding plants 0.6 / 0.75 Printing 0.55/0.7 Quarries 0.5 / 0.7 Rolling Mills (i.e. ,Paper, Steel , etc.) 0.3 / 0.75


3.2.2 Some typical values of reactive power consumption of individual loads are

given below:

Induction motors 0.5 to 1.1 Kvar/KW, at rated output.

Uncontrolled rectifiers 0.3 Kvar/KW.

Controlled rectifiers usually consume much more Kvar/KW than uncontrolled ones and with dependence on the rectifier delay angle.

Arc furnaces around 1 Kvar/KW.

3.2.3 Both controlled rectifiers and arc furnaces of steel mills have a reactive power consumption characterized by a high average value and fast variations. Purely resistive loads, like filament lamps and electric heaters, do not, of course, consume reactive power.

3.2.4 The synchronous motor is the only type of individual load, which can

produce reactive power. It consumes reactive power when under excited and produces reactive power when overexcited. Synchronous motors are usually operated overexcited and thus usually produce reactive power.

3.3 VOLTAGE MANAGEMENT 3.3.1 Control of voltage levels is accomplished by controlling the production,

absorption, and flow of reactive power at all levels in the system. Unlike system frequency, which is consistent throughout an interconnected system in the steady state, voltages experienced at points across the system form a "voltage profile" which is uniquely related to local generation and demand at that instant, and is also affected by the prevailing network arrangements.

3.3.2 Controlling the voltage is a local problem. In other words, the voltage 3.3.2 control problems need to be solved separately by each control area. This

can be achieved by providing sufficient reactive power sources for controlling voltage level as specified in IEGC. The voltage controlling problems can be divided into two situations, which are normal situation and emergency situation.

3.3.3 Voltage changes continuously according to the varying electrical demand,

transmission lines utilization etc. Reactive power (VAR) is required to maintain the voltage to deliver active power (watts) through transmission lines. When there is not enough reactive power, the voltage sags down and it is not possible to push the power demanded by loads through the lines.

Excess of MVAr high voltage

Deficit of MVAr Low Voltage

MVAR balance Good voltage low system losses


3.3.4 Voltage control (keeping voltage within defined limits) in an electric power

system is important for proper operation of electric power equipment and saving it from imminent damage from overheating, to reduce transmission losses and to maintain the ability of the system to withstand disturbances

and prevent voltage collapse. In general terms, decreasing reactive power causes voltages to fall, while increasing reactive power causes voltages to rise.

3.3.5 Voltage stability

a) Voltage stability‖ is the ability of the power system to maintain steady acceptable voltages at all buses in the system under normal operating conditions and after being subjected to disturbance. A system enters steady voltage instability when a disturbance (An increase in load demand, or change in system conditions) causes a progressive and uncontrolled drop in voltage.

b) A system is voltage unstable, if for at least one bus in the system, the bus

voltage magnitude decreases as the reactive power injection in the same bus is increased.

c) ‗Voltage Instability‖ is basically caused by non-availability of reactive power

support in some nodes of the network, where the voltage uncontrollably falls. Lack of reactive power may essentially have two origins,

i. Gradual increase of power demand where the reactive requirement at some buses cannot be met. ii. Sudden change of network topology redirecting the power flows in such a way that the reactive power cannot be delivered at some buses.

d) The increased load is always accompanied by a decrease of voltage except in the case of a capacitive load. When the loading is further increased, the maximum loadability point is reached, from which no additional power can be transmitted under those conditions.

In case of constant power loads, the voltage in the nodes become uncontrollable and rapidly decreases. 3.3.6 VOLTAGE COLLAPSE:

a) When voltages in an area are significantly low or blackout occurs due to the cascading events accompanying voltage instability, the problem is

considered to be a voltage collapse phenomenon. Voltage collapse normally takes place when a power system is heavily loaded and/or has limited reactive power to support the load. The limiting factor could be the lack of reactive power (SVC and generators hit limits) production or the inability to transmit reactive power through the transmission lines.


b) The main limitation in the transmission lines is the loss of large amounts of reactive power and also line outages, which limit the transfer capacity of reactive power through the system.

c) In the early stages of analysis, voltage collapse was viewed as a static

problem but it is now considered to be a non linear dynamic phenomenon. The dynamics in power systems involve the loads and voltage stability is directly related to the loads. Hence, voltage stability is also referred to as load stability.

3.3.7 PROCEDURES FOR CONTROLLING VOLTAGE AND REACTIVE

POWER:-

a) The control of voltage level is accomplished by controlling the production,

absorption and flow of reactive power at all levels in the system. (Refer Table –1 for sources and sinks of reactive power.)

b) Primary Voltage Control: RLDCs shall control primary voltage by

providing specific voltage levels to generators according to the requirement. The generators shall adjust the AVR which will vary the excitation of generating units in order to achieve the specified voltage levels. For other voltage control equipment such as SVCs or automatic tap changing transformers, they are considered to be a part of primary voltage control. All equipment that is used for the primary voltage control is considered to be dynamic.

c) Secondary Voltage Control: The control centers shall employ voltage

control mechanism by managing static reactive power sources, both


absorption and injection, for examples, shunt reactors, capacitor bank, etc, all of which are within the considered zones in cooperate with the first step for voltage control in order to maintain specified voltage levels at essential delivery points that represent the zones.

d) As defined in the IEGC Section 5.2(s), the operating range of the voltages at

various voltage levels of the grid are as follows:

Voltage (kV-rms)

Nominal Minimum Maximum

765 728 800

400 380 420

220 198 245

132 122 145

110 99 121

66 60 72

33 30 36

The maximum and minimum values in the above table are the outer limits and all the regions shall endeavour to maintain the voltage level within the above limits. The steady state voltage is maintained within the limits given in above table. However, the step change in voltage may exceed the above limits where simultaneous double circuit outage of 400 kV lines are considered. In such cases, it may be necessary to supplement dynamic VAR resources at sensitive nodes.

e) SLDC/RLDC may direct a wind farm to curtail its VAr drawal/Injection on considering system security or safety of personnel/equipments.

f) The control centers shall apply the following mechanism for voltage control

in general.

i) Generating units of all the region shall keep their Automatic Voltage Regulators (AVRs) in operation and power system stabilizers (PSS) in AVRs shall be tuned in line with clause 5.2(k) of IEGC.

ii) The transformer tap positions on different 765kV, 400kV & 220kV class ICTs

& GTs shall be changed as per requirements in order to improve the grid voltage.

iii) Disconnecting transmission lines:-This procedure shall be mainly used during light load period, and it shall not reduce system security below N -1 criteria. For other periods, this procedure shall not be used.

iv) Adjusting synchronous condensers. v) Opening or closing shunt reactors and capacitor banks.


g) Switching off of the lines in case of high voltage:-

i) In the event of persistent high voltage conditions when all other reactive control measures as mentioned earlier including opening of redundant HT lines within the state system by the concerned SLDCs have been exhausted,

selected 400 / 230 / 220 / 132 / 110 KV lines shall be opened for voltage control measures.

ii) The opening of lines and reviving them back in such an event would be carried out as per the instructions issued by RLDC/NLDC in real time and as per the standing instructions issued from time to time. While taking such action, RLDC/NLDC would duly consider that to the extent possible the same does not result in affecting ISGS generation as well as the system security & reliability is not affected.

h) VAR Exchange by regional constituents for Voltage and Reactive Control:

i. 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.

ii. The RLDC and 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 is 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.

i) VAR generation / absorption by generating units: - In order to improve the overall voltage profile, the generators shall run in a manner so as to have counter balancing action corresponding to low/high backbone grid voltage and to bring it towards the nominal value. In order to achieve the same, all generators shall generate reactive power during low voltage conditions and absorb reactive power during high voltage conditions as per the capability limit of the respecting generating units.

j) Load Management for controlling the Voltage:- All the regions shall

identify the radial feeders in their areas in consultation with SLDCs which have significant reactive drawls and which can be disconnected in order to improve the voltage conditions in the event of voltage dropping to low levels. The details of all such feeders shall be kept ready in the respective control rooms of RLDC/SLDC and standing instruction would be given to


the operating personnel to ensure the relief in the hour of crisis by disconnecting such feeders.

k) Following corrective measures shall be taken in the event of voltage going

high / low:-

1. In the event of high voltage (when the bus voltage going above 410 kV), following specific steps would be taken by the respective grid substation/generating station at their own, unless specifically mentioned by NLDC/RLDC/SLDCs.

i) The bus reactor be switched in

ii) The manually switchable capacitor banks be taken out iii) The switchable line/tertiary reactors are taken in. iv) Optimize the filter banks at HVDC terminal v) All the generating units on bar shall absorb reactive power within the

capability curve. vi) Operate synchronous condensers wherever available for VAR absorption. vii) Operate hydro generator / gas turbine as synchronous condenser for VAR

absorption wherever such facilities are available. viii) Bring down power flow on HVDC terminals so that loading on parallel

EHV network goes up resulting in drop in voltage. ix) Open lightly loaded lines in consultation with RLDC/SLDC for ensuring

security of the balanced network. 2. In the event of low voltage (when the bus voltage going down below

390kV), following specific steps would be taken by the respective grid substation/generating station at their own, unless specifically mentioned by NLDC/RLDC/SLDCs.

i) Close the lines which were opened to control high voltage in consultation with RLDC/SLDC.

ii) The bus reactor be switched out iii) The manually switchable capacitor banks are switched in. iv) The switchable line/tertiary reactor are taken out v) Optimize the filter banks at HVDC terminal. vi) All the generating units on bar shall generate reactive power within

capability curve. vii) Operate synchronous condenser for VAR generation.

viii) Operate hydro generator / gas turbine as synchronous condenser for VAR generation wherever such facilities are available.

ix) Increase power flow on HVDC terminals so that loading on parallel EHV network goes down resulting in rise in voltage.


l) SYSTEM FREQUENCY & VOLTAGE CONTROL:-

i) This option is rarely used say for example when two islands has to be synchronized and voltage has to be controlled at the end where line has to be synchronized.

ii) Voltage of the large interconnected grid can also be controlled by controlling

the system frequency. As per Modern Power Station Practice, System Operation Volume-I (2), the general synchronous machine equations shows that voltage levels are directly proportional to frequency and for good voltage control extremes of system frequency must be avoided.

E=4.44øf N. Where: E is the EMF Generated; f is the Frequency, ø the flux. iii) Times of low frequency are usually associated with plant shortage. The

reactive capability is low as the units are running at rated MW capacity; any increase in reactive power would only be at the cost of reduction in MW output, something that is not usually allowed as per the Indian Electricity Grid Code section 6.6 Para 6.

m) Adverse weather conditions and voltage control

As per Modern Power Station Practice, System Operation Volume-L [2], Fog or other conditions of high humidity give an increased risk of insulation flashover which can be minimised by reducing voltage levels. However under critically loaded conditions, it is judged that the risk of running with reduced voltage levels outweighs the risk of tripping and the technique of lowering the voltage shall not be used.


4.Transmission lines and reactive power compensation

4.1 INTRODUCTION

4.1.1 Transmission lines are characterized by a series resistance, inductance, and

shunt capacitance per unit length. These values determine the power-carrying capacity of the transmission line and the voltage drop across it at full load. AC resistance of a conductor is always higher than its DC resistance due to the skin effect forcing more current flow near the outer surface of the conductor.

4.1.2 In moving power from generators to loads, the transmission network

introduces both real and reactive losses. Housekeeping loads at substations (such as security lighting and space conditioning) and transformer excitation losses are roughly constant (i.e., independent of the power flows on the transmission system). Transmission-line losses, on the other hand, depend strongly on the amount of power being transmitted.

4.1.3 The series inductive reactance of a transmission line depends on both the

inductance of the line and the frequency of the power system. 4.1.4 Transmission lines are characterized by their distributed parameters:

distributed resistance, inductance, and capacitance. The distributed series and shunt elements of the transmission line make it harder to model. Such parameters may be approximated by many small discrete resistors, capacitors, and inductors.

Transmission line model 4.1.5 The consumption of reactive power by transmission line increases with the

square of current i.e., the transmission of reactive power requires an additional demand for reactive power in the system components.

4.1.6 Thus, when it is critically needed during large power transfers, reactive

power is the most difficult to transport. In order to obtain an acceptable voltage level, reactive power generation and consumption have to be situated as close to each other as possible to avoid excessive transmission.

4.1.7 When reactive losses are negative, the line is supplying reactive power;

when they are positive, it is consuming reactive power.


4.2 SURGE IMPEDANCE LOADING (SIL)

4.2.1 Transmission lines and cables generate and consume reactive power at the

same time. The transmission lines have both capacitive and inductive

properties. The reactive power generation is almost constant, because the capacitance of the line is usually constant, and the line‘s reactive power consumption depends on the current or load connected to the line that is variable. So at the heavy load conditions transmission lines consume reactive power, decreasing the line voltage, and in the low load conditions – generate reactive power, increasing line voltage.

4.2.2 The case when line‘s reactive power produced by the line capacitance is

equal to the reactive power consumed by the line inductance is called natural loading or Surge Impedance Loading (SIL) meaning that the line provides exactly the amount of MVAr needed to support its voltage. The balance point at which the inductive and capacitive effects cancel each other is typically about 40% of the line‘s thermal capacity. Lines loaded above SIL consume reactive power, while lines loaded below SIL supply reactive power.

4.2.3 Impedance which is connected to the line at the Surge Impedance loading is

called Characteristic Impedance (Surge Impedance) (Zc) and is equal to =sqrt (X/B) where X is the reactance and B is the susceptance of the transmission line in per unit. Defining in terms of inductance (L) and capacitance (C), Surge impedance (SI) would be equal to sqrt (L/C). 4.2.4 The amount of reactive power consumed by a line is related to the current flowing on the line or the voltage drop along the line. The amount of reactive power supplied by a line is related to the line voltage. An ideal line with zero resistance (zero real losses) that is loaded at its surge impedance loading will have the same voltage at both ends because it is not supplying or consuming reactive power. 4.2.5 The surge impedance loading of a 400 kV twin Moose uncompensated line would be 517 MW as shown in below example – 4.1. Example-4.1 For a twin Moose 400 kV line the SIL can be worked out as follows:- Susceptance of 400kV Twin Moose per Km=3.46874E-06 Mho Converting to per unit B in pu is = 3.46874E-06*400*400/100 = 0.00554998 Reactance(X) of a 400kV Twin Moose per Km = 0.332 Ohms. Converting to per unit X in pu is = 0.332*100/(400*400)


= 0.0002075 Zc =Sqrt (X/B) = 0.19335 SIL in MW = 100/ Zc= 517.17 MW 4.2.6 A 400 kV, line generates approximately 55 MVAR per 100 km/Ckt, when it

is idle charged due to line charging susceptance. This implies a 300 km line generates about 165 MVAR when it is idle charged. 4.3 SIL FOR DIFFERENT CONDUCTORS AND VOLTAGES


4.4 LINE LOADING AS FUNCTION OF LENGTH AND COMPENSATION & ST. CLAIRE’S CURVE

4.4.1 The SIL is usually much lower than the thermal rating. Below 69 kV the line

charging is usually negligible while it is a significant source of reactive

power for long lines of higher system voltages. The maximum permissible line loadings derived from St. Clair‘s curve. SIL given in table above is for uncompensated line. Further in order to take into account the compensation, SIL has to be recalculated. After that, the modified SIL has to be multiplied by the factor derived from St. Clair's curve.

4.4.2 Compensation using a Shunt Reactor

If k is the compensation then:

In case of compensation (Shunt reactors and series capacitors) the SIL of the line changes. Shunt reactors cause the SIL to decrease by a factor of

.(1-k), where k is the degree of compensation defined as (S+R)/C Where S is sending end reactor converted to 400 kV (MVAR) R is receiving end reactor converted to 400 kV (MVAR)

C is the charging MVAR of the line (MVAR) Hence SILmodified= SILuncomp * √ (1-k)

4.4.3 Compensation using a Series Capacitor

Series capacitor causes the SIL to increase by a factor divisible by. (1- k) where k is degree of compensation. Hence SILmodified = SILuncomp / √ (1-k)

Finally the derived steady state limit for a line would be = SIL modified x factor from St. Clair's curve From the example 4.1, the SIL calculated for 400 kV twin Moose uncompensated line without considering the length is 517MW. In the below example 4.2, the SIL of 400kV twin moose has been calculated by considering length and shunt reactive compensation. 4.4.4 Example-4.2 Let us now consider a 300 KM, Twin Moose Conductor, 400 kV S/C line with 50 MVAR Reactor at both ends. The Reactors are rated for 420 kV and hence have to be converted to 400 kV • Reac(NEW) = Reac(old) X (400^2)/ (420^2)= 45.35 MVAR • The Charging MVAR for a 300 kM long line is 165 MVAR (at 55MVAR per 100 KMS) • In case of Shunt Compensated lines, the degree of compensation (k) is the sum of Reactors at both ends divided by line charging MVAR, which is equal to (45.35+45.35)/165 = 0.55


The new Steady State Limit would then be =517 MW * √ (1-k)* St Claire Curve Point =517 MW * √ (1-k)* 1.3 where k= 0.55 and 517 MW is the SIL without compensation & 1.3 is the St

Claires Curve point corresponding to 300 Kms as shown in the figure below. = 347 MW * 1.3 = 451 MW

ST. CLAIRE‘S CURVE 4.5 SHUNT REACTORS AND REACTIVE POWER CONTROL 4.5.1 Electric transmission lines have both capacitive and inductive properties. Shunt reactors are used to compensate for the effects of line capacitance, particularly to limit voltage rise on open circuit or light load and switching operations. They are usually required for EHV overhead lines longer than 200 km. A shorter overhead line may also require shunt reactors if the line is supplied from a weak system (Low short circuit Capacity). 4.5.2 The use of shunt reactive devices. i.e. shunt compensation, is a

straightforward reactive-power compensation method. The shunt reactors are sized in such a way that under steady state condition, switching on and off of the reactors shall not cause a voltage change exceeding 5 %.

4.5.3 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. by each region which can be switched off in order to improve the system voltage profile. The switching off of such line reactors and reviving them back would be carried out as per the instructions issued by RLDCs/SLDCs.

4.5.4 The standard sizes of the reactors are

4.5.5 A shunt Reactor of sufficient size must be permanently connected to the line

to limit fundamental-frequency temporary over voltage to about 1.5 pu for a duration of less than 1 second. Such line connected reactors also serve to limit energization over voltage (switching transients). Additional shunt reactors (i.e. Bus Reactors) may be connected to the EHV bus or to the tertiary windings of adjacent transformers to maintain normal voltage under light-load conditions. During heavy loading conditions when system voltage is low, some of the line/bus reactors (those are switchable i.e. provided with circuit breaker) may have to be disconnected.

4.5.6 Shunt reactors are similar in construction to transformers, but have a single

winding (per phase) on an iron core with air gaps and immersed in oil. They may be either single phase or three phase construction. Normally there are two types of shunt reactors – Line reactor and bus reactor. Line reactor‘s functionality is to avoid the switching and load rejection over voltages where as Bus reactors are used to avoid the steady state over voltage during light load conditions.

4.5.7 They can be either permanently connected to the system or switchable one.

Use of shunt rectors at normal operating condition may reduce system voltage and increase losses. Hence switchable reactors are better choice since they can be switched off whenever it is not required.

4.5.8 The degree of compensation being decided by an economic point of view

between the capitalized cost of compensator and the capitalized cost of reactive power from supply system over a period of time. In practice a compensator such as a bank of capacitors (or inductors) can be divided into parallel sections, each switched separately, so that discrete changes in the compensating reactive power may be made, according to the requirements of the load.

kV Level Size in MVAr 3-Phase/1 Phase

400 kV 50,63,80,93, 125 3-Phase Units

765 50,63,80,110 1-Phase units


4.5.9 Voltage change at bus due to removal / addition of reactor :- The approximate percentage voltage rise/fall of a bus due to removal/addition of a reactor of capacity Q MVAR is as follows: = Q*100 / Fault MVA of the Bus For example removing a 80 MVAR bus reactor at a bus of 5000 MVA SC

level would cause the voltage to rise by 1.6% i.e. 400*1.6/100 =6.4 KV

4.5.10 List of inter regional lines ( 400kV and above) with reactor details is given in

Annexure 1. 4.5.11 In Annexure 2, the details about total reactive compensation available

through bus reactors and line reactors at all India Level are explained. 4.5.12 Selection of lightly loaded lines for voltage control:- When a particular

line is opened, the MVAR relief available for that line opening is estimated for all the 400kV and above transmission lines for all the region.

In addition to that, if the line has the provision for using line reactor as bus reactor by manually or through switching arrangements, then the MVAR relief available for those lines also calculated. This is explained in Annexure 3.

4.5.13 400kV & 765kV Reactors installed capacity at all India level is attached as

Annexure 4.

4.5.14 Fault level in substation:- Fault level of substation besides giving an idea

about the maximum breaking current possible of that substation, it also gives an idea about sensitivity of bus voltage to the reactive power injection or drawl. Fault level of 400kV & above Buses is attached as Annexure 5.

4.5.15 Surge Impedance Loading of the transmission lines is given in

Annexure 6.

4.5.16 List of 765kV lines to be commissioned during 2012 is given in Annexure 7.


5. Series and shunt capacitors—their effect on reactive power

5.1 SHUNT CAPACITORS 5.1.1 There has been a phenomenal growth in the use of shunt capacitors as a

means of local provisions of reactive power, particularly within distribution systems. Shunt capacitors supply reactive power and boost local voltages thereby enhancing the system capacity and reducing the losses.

5.1.2 The presence of these in distribution system reduces the transfer of reactive

power from EHV system, thereby contributes to efficiency of power transmission & distribution.

5.1.3 They are used throughout the system and are applied in a wide range of

sizes. Shunt capacitors are used to compensate for the I2X losses in

transmission system and to ensure satisfactory voltage levels during heavy loading conditions. 5.1.4 The advantages of shunt capacitors are their low cost compared to SVCs

and their flexibility of installation and operation. 5.1.5 The principal disadvantage of shunt capacitors is that their reactive power

output is proportional to the square of the voltage. The reactive power output is reduced at low voltages when it is likely to be needed most. As the voltage falls the reactive power supplied by the capacitors decreases according to the square of the voltage, causing voltage to fall further.

5.1.6 Precise and speedy control of voltage is not possible as capacitor banks are

discrete devices, but they are often configured with several steps to provide a limited amount of variable control.

5.1.7 Objective of shunt capacitor units are : • Increase voltage level at the load • Improves voltage regulation if the capacitor units are properly switched.

• Reduces I2R power loss in the system because of reduction in current.

• Increases power factor of the source generator. • Decrease kVA loading on the source generators and circuits to relieve an overloaded condition or release capacity for additional load growth.

• By reducing kVA loading on the source generators additional kilowatt loading may be placed on the generation if turbine capacity is available.


5.1.8 Capacitor Banks are sets of capacitors which are connected to the system through mechanical switches of circuit breakers and their real power losses

are very small. The capacitors in a bank are switched in blocks. Switching of capacitor banks provides a convenient means of controlling transmission system voltages. Switched capacitors cannot smoothly adjust their reactive

power output because they rely on mechanical switches and take several cycles (less than one second) to operate. 5.1.9 When capacitors are switched out, they must be discharged before reconnection, normally with discharge time ranging from two to fifteen

minutes. In some special applications, capacitor banks are equipped with fast discharge reactors. Hence switching speeds can be quite fast with current limiting reactors to minimize switching transients that will discharge the capacitors in about 120 milliseconds(ms) thus enabling them to be reconnected to provide voltage support to the power system.

5.1.10 Capacitor banks at the distribution level are often not switched off at high voltages as the operators are reluctant to interrupt capacitive currents (perceived maintenance issues) or the high voltages in the super-grid have not percolated to the distribution level due to sub-optimal taps. Though switching off the capacitors is more of a pre-emptive and administrative issue rather than a real time undertaking, a judicious action in the matter can certainly alleviate the problem of high voltage. 5.2 SERIES CAPACITORS

5.2.1 In series capacitors the reactive power is proportional to the square of the load current, thus generating reactive power when it is most needed whereas in shunt capacitors it is proportional to the square of the voltage. S 5.2.2 OBJECTIVES OF SERIES COMPENSATION

Reduction in line voltage drop – Although the line voltage drop is reduced during high load periods the voltage at the receiving end will rise during light load periods.

Effect on the load flow in parallel lines – As the impedance of the compensated line is reduced, loading of parallel lines is reduced.

Increase of transmission capability – The compensated line can be loaded closer to its thermal limit. Increase of stability margin – For the same power flow, the angular separation of the bus voltages across the compensated line will be less.

5.2.3 The reactive power produced by a series capacitor increases with increasing

power transfer. Series capacitors are normally installed in 220kV and above systems. They reduce net transmission line inductive reactance.


5.2.4 Series capacitors are connected in series with the line conductors to compensate for the inductive reactance of the line. Series capacitors compensation is usually applied for long transmission lines and transient

stability improvement. The reactive generation I2XC compensates for the

reactive consumption I2XL of the transmission line. This is a self-regulating

nature of series capacitors. But at light loads series capacitors have little effect.

5.2.5 There are certain unfavorable aspects of series capacitors. Generally the cost

of installing series capacitors is higher than that of a corresponding installation of a shunt capacitor. This is because the protective equipment for a series capacitor is often more complicated.

5.2.6 Typical degrees of compensation vary from 30% to 70% of the line

impedance. Values below 30% do not contribute substantially to any

improvement. Values beyond 70% endanger the stability of the network.

5.2.7 Subsynchronous resonance (SSR):- Subsynchronous resonance (SSR) is a dynamic phenomenon of interest in power systems that have certain special characteristics. The formal definition of SSR provided by the IEEE is

Subsynchronous resonance is an electric power system condition where the electric network exchanges energy with a turbine generator at one or more of the natural frequencies of the combined system below the synchronous frequency of the system. The definition includes any system condition that provides the opportunity for an exchange of energy at a given subsynchronous frequency. This includes what might be considered "natural" modes of oscillation that are due to the inherent system characteristics, as well as "forced" modes of oscillation that are driven by a particular device or control system. The most common example of the natural mode of subsynchronous oscillation is due to networks that include series capacitor compensated transmission lines.

5.2.8 Comparison between shunt and series compensation is shown in the below

table.

S.N

Shunt compensation Series compensation

1. The shunt unit is connected in parallel across full line voltage. The current through the shunt capacitor is nearly constant as the supply terminal voltage and its reactance are constant.

The series unit is connected in series in the circuit and therefore conducts full current

2. The voltage across the shunt capacitor is substantially constant as

The voltage across the series capacitor changes instantaneously as it depends on


S.N


it is equal to the system voltage and generally within certain limits of say 0.9 to 1.1 pu.

the load current through it, which varies from 0 to ILmax

3. The power developed across the shunt capacitor is

Csh KVAR = CshcSH x

vv

x

v 2

.

The power developed across the series capacitor is

Cse KVAR = (IL XCse) (IL)= IL2 XCse

4. The shunt capacitor supplies lagging reactive power to the system. Hence directly compensating the lagging KVAR load. It improves the load power factor substantially. Hence its main purpose is to compensate the load Power factor

The series capacitor reduces the line reactance as it introduces leading reactance in series of the line. Thus series capacitor at rated frequency Compensates for the drop, through inductive reactance of the feeder. Hence it is used to increase the line transmission capacity.

5. The size and capacity of shunt capacitor is generally higher for the same voltage regulation

The size and capacity of a series capacitor is relatively lesser for the same voltage regulation

6. Not suitable for transient voltage drops caused by say, frequent motor starting, electric welding etc.

The voltage regulation due to series capacitor is proportional to the IL2 hence it meets the requirements of transient voltage changes

7. Performance is dependent on terminal voltage. Hence not effective in fluctuating voltage conditions.

The performance does not depend on the system voltage variations. But depends on system load current. Hence gives full output under low voltage and heavily loaded conditions

8. The shunt capacitor need not be on the source side. But closer to the load point

The series capacitor should always be on the source side of the load.

9. The rating is based on

KVARCsh = KW(Tan1 - Tan2)

where 1 is the power factor angle

before correction, 2 is the pf angle after correction

The rating is based on percentage compensation of the line reactance. Generally XCse = 0.3 to 0.4 of Xline Ex:

A 220KV, 0.4/km, 100km line, 40%, XL

= 0.4 X 100 = 40, Xcse = 0.4 x

40 = 16 = 1/2fCse Cse =

FFx

x 200

16314

101 6

10. The Ferranti effect is aggravated by shunt compensation

The Ferranti effect is reduced by the series capacitor


S.N


11. Power transferred through a line

P=Sin

X

VV rs

with shunt capacitor, Vr increases P increases

With Cse, Vr increases and X decreases hence P increases much more.

12. The shunt compensation does not require special protection arrangements as the terminal voltage of the capacitor bank falls under fault conditions

The voltage across series capacitor abnormally rises due to flow of fault current through it. Hence it requires special protection schemes.

5.2.9 Shunt capacitors installed capacity at all India level is attached as

Annexure 8.

5.2.10 List of Series Compensation schemes at all India level is attached as Annexure 9.


6.Transformer tap changer effect on reactive power

6.1 In line with IEGC clause 6.6.5 & 6.6.4, the transformer tap positions on different 765kV, 400kV & 220kV class ICTs & GTs shall be changed as per requirements in order to improve the grid voltage. RLDCs shall coordinate and advise the settings of different tap position and any change in their positions shall be carried out after consultation with RLDC. Normally tap position of all the ICTs shall be reviewed/changed at every three month interval.

6.2 Transformers with tap-changing facilities constitute an important means of controlling voltage throughout the system at all voltage levels. Coordinated

control of the tap changers of all the transformers interconnecting the subsystems is required if the general level of voltage is to be changed.

6.3 The OLTC allows voltage regulation and/or phase shifting by varying the turns ratio under load without interruption. Large power transformers are generally equipped with ―voltage tap changers,‖ sometimes called ―taps‖ with tap settings to control the voltages either on the primary or secondary sides of the transformer by changing the amount and direction of reactive power flow through the transformers. Transformer taps can be controlled automatically based on local system conditions or manually.

6.4 Generating Transformer: - Power generated at generating station (usually at the range of 11kV to 25kV) is stepped up by generating transformer to the voltage level of 220, 400, 765kV for transmission. It is one of the important and most critical components of power system. They are generally provided with off circuit tap changer with a small variation in voltage because the voltage can always be controlled by the field of generator. Generating Transformer with OLTC also used for reactive power control.

6.5 Interconnecting Transformer: - Normally autotransformers are used to interconnect two grid/systems operating at two different voltage levels (400 and 220kV). They are normally located between generating transformer and receiving end transformer. In autotransformer there is no electrical isolation between primary and secondary. Some volt-amperes are conductively transformed and some are inductively transformed. Synchronous condenser or shunt reactors are connected to the tertiary for reactive compensation if required. Normally 400/220kV ICTs having the following tap setting:

- 1 to 17 taps and 5 kV per tap


- ±10% range − Nominal tap at 9

6.6 The OLTC alters the power transformer turns ratio in a number of pre defined steps and in that way changes the secondary side voltage.

Transformer-tap changers can be used for voltage control, but the control differs from that provided by reactive sources. Transformer taps can force voltage up (or down) on one side of a transformer, but it is at the expense of reducing (or raising) the voltage on the other side. Tap changers do not consume or supply reactive power.

6.7 To increase reactive power output and raise system voltage levels at the

substation to which the generator is connected, the generator transformer (GT) is tapped (usually off load) in a direction to increase its transformation ratio. This will depress the stator volts which are immediately restored by the AVR increasing the machine excitation.

6.8 Typically a 500 MW generator transformer will have 15 taps and a no load

voltage regulation of +2% to 16%, the asymmetry reflecting the higher

MVAr generation (as opposed to absorption) capability. Tap 1 is usually the

position of highest transformation ratio and MVAr output, and tap 15 the

position of lowest ratio and maximum MVAr absorption. 6.9 The taps of all the plants directly connected to 400 kV or 200 kV level networks in an area are simultaneously changed. The theory behind this is

that when generating stations are acting independently to control their local substation voltages, an individual station reaching its reactive generation

limit may tap to reduce its reactive output. Such action will be at the

expenses of neighboring stations and net effect is to reduce system voltage

levels and increase the total reactive generation required by reason of higher circuit reactive losses. 6.10 Coordinated action instead by all stations to tap in a direction to increase the

system voltage level will reduce the network reactive demand (lower I2X,

increase B2V) and move all generators away from their lagging reactive

limits. Thus simultaneous tap changing avoids a situation whereby MVArs

produced at one station are negatively compensated at others. 6.11 The reactive power consumption of a transformer at rated current is within

the range 0.05 to 0.2 p.u. based on the transformer ratings. Fixed taps are useful when compensating for load growth and other long term shifts in system use. LTCs are used for more-rapid adjustments, such as compensating for the voltage fluctuations associated with the daily load cycle. While LTCs could potentially provide rapid voltage control, their performance is normally intentionally degraded. With an LTC, tap changing


is accomplished by opening and closing contacts within the transformer‘s tap changing mechanism.

6.12 The ICTs TAP position details at all India level is given in Annexure 10. 6.13 Typical Transformer Tap changer both online/offline is given in Annexure 11. 6.14 The below fig illustrates possible the transformer tap operating zones which

gives best results.


7. HVDC operation effect on reactive power

7.1 For transferring power over a long distance, High voltage DC transmission lines (HVDC) are preferred. They normally consist of two converter terminals connected by a DC transmission line and in some applications, multi-terminal HVDC with interconnected DC transmission lines. Back-to-Back DC and Voltage Source Converter based (VSC) HVDC are specific types of HVDC systems. VSC based HVDC system uses new cable and converter technologies and is economical at lower power levels than traditional HVDC.

7.2 Back-to-Back HVDC is used for asynchronous connection of two AC

systems with different system characteristics (for example between ‗N-E-W‘ grid AND Southern Grid in India at Gazuwaka and Bhadrawati) or within an AC system for AC power flow regulation on the parallel AC network (for example at Vindhyachal and Pusauli in ‗N-E-W‘ grid).

7.3 The converter terminals consist of thyristor based converters, converter

transformers, filters and capacitors all of which facilitate conversion from power from AC to DC and vice versa. In addition to voltage conversion, the converters are capable of controlling the amount of power flows and direction over the DC transmission line.

7.4 Because DC transmission lines are transmitting power at zero hertz, the

reactive power consumption on the line is zero. The converters require reactive power for the conversion process typically in the range of 40% of the power rating of each of the converter terminals. Therefore, for a 1000 MW HVDC transmission, 400 MVAR is typically required at each terminal. 7.5 The reactive power is required to compensate for the reactive power

consumption in the converter transformers and to maintain an acceptable AC voltage level on the AC side of the converter terminals. Much of this reactive power requirement is provided by shunt capacitors and filters, which are required to filter out or reduce the harmonic currents resulting from AC waveform chopping in the AC-DC conversion processes. 7.6 Therefore, a properly designed HVDC system is essentially self-sufficient in

reactive power. Due to its inherently fast electronic control, it is also capable of supporting the AC terminal voltages by controlling the DC power flow over the line and consequently the reactive power consumption in the converter transformers. 7.7 It may be further noted that while the reactive power generated by the

switching of filters varies in steps, the reactive power requirement by the Converter transformer varies continuously (not in steps) with the power


level. Hence while selecting and/or varying the power level, corresponding to each point there may be an excess/deficit reactive power at the HVDC station and the same would eventually get injected/ drawn to/from the Grid causing voltage rise/drop. Depending upon whether voltage is required to be increased or decreased, the set point may be decided

accordingly. 7.8 While deciding the quantum of diversion/wheeling, the different power

levels at which the filters get switched on/off may be kept in mind, so that voltage can be maintained at desired level. For this purpose the following two points are important in this regard: Reactive Power generation at HVDC bipole stations at different Power levels vis-à-vis MVAR requirement of the Converter transformer is to be considered. Based on this , when a particular set point is required, the same may be optimized to the nearest threshold value so that number of filters that get switched on/off would control the Bus voltage at other end substation to the desired level. 7.9 At any point of time filter banks at HVDC stations in service depends on

power flow magnitude and / or direction of power flow. Therefore, the power order on HVDC bi-pole could be kept at appropriate level to bring in or take a filter bank in services.

7.10 The table 7.1 shows the information about HVDC TALCHER/KOLAR bi-

pole filter details and reactive power generation.

Table 7.1 REACTIVE POWER GENERATION AT TALCHER/KOLAR HVDC STATIONS AT DIFFERENT POWER LEVELS


7.11 VOLTAGE SOURCE CONVERTERS

7.11.1 Voltage source converters technology use high power self-turn off type semiconductor devices such as IGBT. The use of IGBTs in VSC technology eliminates the need of active commutation voltage and also allow for higher

switching frequencies which reduces the harmonic content. A higher switching frequency reduces the filter requirement on AC side when compared to conventional HVDC. Pulse width modulation is used for switching of semiconductor devices in VSC based HVDC transmission.

7.11.2 VSC converters combined with an energy storage source permits

continuous and independent control of real and reactive power in power transmission. Reactive power control can be used for dynamic voltage regulation to support the interconnecting ac system following contingencies. This capability can increase the overall transfer levels. Forced commutation with VSC permits black start, i.e., the converter can be used to synthesize a balanced set of three phase voltages much like a synchronous machine.

7.11.3 Some of the advantages of VSC based transmission are:

a) Independent control of reactive and active power

b) Reactive control independent of other terminal

c) Simpler interface with ac system

d) Compact filters

e) Provides continuous ac voltage regulation

f) No minimum power restriction

g) Operation in extremely weak systems

h) No commutation failures

i) No restriction on multiple infeeds

j) No polarity reversal needed to reverse power

k) Black-start capability

l) Variable frequency

7.12 Interaction between two neighbouring HVDC system:-

7.12.1 HVDC systems have traditionally been operated in relative electrical isolation from each other. Two or more HVDC links operating electrically close to each other is referred to as Multi-Infeed HVDC system. Multi-

infeed converters either share a common ac bus or connected to buses that are electrically close. The operation of adjacent dc terminals poses serious


concerns for mutual interaction following a disturbance in either dc systems or in the common AC system.

7.12.2 The main potential problems arising from Multi-Infeed HVDC systems

include small signal stability, commutation failure, voltage instability and

collapse. In order to cope with the possible adverse interactions, Co-ordination between the HVDC controls is the most effective solution. Co-ordination between controls includes equipping converters with voltage stabilizing controls, using of adequate series and shunt reactive power compensation devices at the critical AC transmission lines and also using fast power flow controllers.

7.13 HVDC BIPOLE CONFIGURATION 7.13.1 In bipolar transmission a pair of conductors is used, each at a high potential with respect to ground, in opposite polarity. Since these conductors must be insulated for the full voltage, transmission line cost is higher than a monopole with a return conductor. However, there are a number of advantages to bipolar transmission which can make it the attractive option. 7.13.2 Under normal load, negligible earth-current flows, as in the case of mono polar transmission with a metallic earth-return. This reduces earth return loss and environmental effects. When a fault develops in a line, with earth return electrodes installed at each end of the line, approximately half the rated power can continue to flow using the earth as a return path, operating in mono polar mode. 7.13.3 Since for a given total power rating each conductor of a bipolar line carries only half the current of mono polar lines, the cost of the second conductor is reduced compared to a mono polar line of the same rating. In very adverse terrain, the second conductor may be carried on an independent set of transmission towers, so that some power may continue to be transmitted even if one line is damaged. 7.13.4 A bipolar system may also be installed with a metallic earth return conductor as being envisaged for future HVDC projects such as Chamba- Kurukshetra etc. This is considering the adverse effect of even small ground currents on equipments such as pipelines etc. 7.13.5 The following bipole HVDC systems are in operation.

a) HVDC Rihand-Dadri bipole: Capacity 2 X 750 MW, +/- 500 kV DC, 815 km b) HVDC Chandrapur-Padge bipole: Capacity 2X750MW, +/-500kV DC c) HVDC Talcher - Kolar bipole: Capacity 2 X 1250 MW, +/- 500 kV DC,

1440 km


d) HVDC Balia-Bhiwadi bipole: Capacity 2X1000MW, +/-500kV DC, 790km

7.13.6 800 KV HVDC BI-POLE:- The first 800kV HVDC bi-pole line in INDIA has been planned from pooling substation at Bishwanath Chariyali in North - eastern Region to Agra in Northern region. This is being programmed for

commissioning matching with Subansiri Lower HEP in 2012-13. The transmission line would be for 6000 MW capacity and HVDC terminal capacity would be 3000 MW between Bishwanath Chariyali and Agra. In the second phase, for transmission of power from hydro projects at Sikkim and Bhutan pooled at Siliguri, another 3000 MW terminal modules would be added between Siliguri and Agra. It is envisaged to take-up the proposed 800kV, 6000MW HVDC bi-pole line from Bishwanath Chariyali to Agra under a scheme titled ‖Inter-regional Transmission system for power export from NER to NR/WR‖ which is under execution.

7.14 HVDC BACK TO BACK CONFIGURATION:-

7.14.1 A back-to-back station (or B2B for short) is a plant in which both static

inverters and rectifiers are in the same area, usually in the same building. The length of the direct current line is kept as short as possible.

7.14.2 HVDC back-to-back stations are used for Coupling of electricity mains of different frequency (as in INDIA; the interconnection between NEW GRID and SR GRID through 1000 MW HVDC BHADRAVATI and 1000 MW HVDC GAZUWAKA). In the past, power systems in India were planned on regional basis with asynchronous interconnection through HVDC back-to- back for facilitating opportunity power transaction.

7.14.3 The DC voltage in the intermediate circuit can be selected freely at HVDC back-to-back stations because of the short conductor length. The DC voltage is as low as possible, in order to build a small valve hall and to avoid series connections of valves. For this reason at HVDC back-to-back stations valves with the highest available current rating are used. 7.14.4 A high voltage direct current (HVDC) link consists of a rectifier and an inverter. The rectifier side of the HVDC link is equivalent to a load consuming positive real and reactive power and the inverter side of the HVDC link as a generator providing positive real power and negative reactive power (i.e. absorbing positive reactive power). 7.14.5 Thyristor based HVDC converters always consume reactive power when in operation. A DC line itself does not require reactive power and voltage drop on the line is only the IR drop where I is the DC current. The


converters at the both ends of the line, however, draw reactive power from the AC system. The reactive power consumption of the HVDC converter/inverter is 50-60 % of the active power converted. It is independent of the length of the line.

7.14.6 Both AC and DC harmonics are generated in HVDC converters. AC harmonics are injected into the AC system and DC harmonics are injected into the DC line. These harmonics have the following harmful effects: • Interference in communication system. • Extra power losses in machines and capacitors connected in the system. • Some harmonics may produce resonance in AC circuits resulting in over voltages. • Instability of converter controls. 7.14.7 Harmonics are normally minimized by using filters. The following types of

filters are used: • AC filters. • DC filters. • High frequency filters. 7.14.8 AC Filters:- AC filters are RLC circuits connected between phase and earth.

They offer low impedance to harmonic frequencies. Thus, AC harmonic currents are passed to earth. Both tuned and damped filter arrangements are used. The AC harmonic filters also provide reactive power required for satisfactory operation of converters and also partly injects reactive power into the system.

7.14.9 DC Filters :- DC filters are similar to AC filters. A DC filter is connected between pole bus and neutral bus. It diverts DC harmonics to earth and prevents them from entering DC lines. Such a filter does not supply reactive power as DC line does not require reactive power.

7.14.10 HIGH FREQUENCY FILTERS:- HVDC converters may produce electrical

noise in the carrier frequency band from 20 Khz to 490 Khz. They also generate radio interference noise in the mega hertz range of frequencies. High frequency (PLC-RI) filters are used to minimize noise and interference with PLCC. Such filters are connected between the converter transformer and the station AC bus.

7.14.11 The following back to back HVDC systems are in operation.

a) HVDC back to back Vindhyachal: Between Northern Region and Western Region: Capacity 2 X 250 MW


b) HVDC back to back Pusauli: Between Northern Region and Eastern Region: Capacity 1 X 500 MW

c) HVDC back to back Gazuvakka: Between Eastern Region and Southern Region: Capacity 2 X 500 MW

d) HVDC back to back Bhatravati: Between Western Region and Southern

Region: Capacity 2 X 500 MW


8. FACTS & Reactive power control

8.1 INTRODUCTION

8.1.1 The demand of lower power losses, faster response to system parameter

change, and higher stability of system have stimulated the development of the Flexible AC Transmission systems (FACTS). Based on the success of research in power electronics switching devices and advanced control technology, FACTS has become the technology of choice in voltage control, reactive/active power flow control, transient and steady-state stabilization that improves the operation and functionality of existing power transmission and distribution system. 8.1.2 The achievement of these studies enlarge the efficiency of the existing

generator units, reduce the overall generation capacity and fuel

consumption, and minimize the operation cost. The power electronics based switches in the functional blocks of FACTS can usually be operated repeatedly and the switching time is a portion of a periodic cycle, which is much shorter than the conventional mechanical switches.

8.1.3 The advances in semiconductors increases the switching frequency and voltage-ampere ratings of the solid switches and facilitates the applications. For example, the switching frequencies of Insulated Gate Bipolar Transistors (IGBTs) are from 3 kHz to 10 kHz which is several hundred times the utility frequency of power system (50~60Hz). Gate turnoff thyristors (GTOs) have a switching frequency lower than 1 kHz, but the voltage and current rating can reach 5-8 kV and 6 kA respectively.

8.2 STATIC VAR COMPENSATORS (SVC) :-

8.2.1 Static VAR compensators – combine capacitors and inductors with fast

switching (sub cycle, such as <1/50 sec) timeframe capability. In this voltage is regulated according to a slope (droop) characteristic.

8.2.2 Static Var Compensator is ―a shunt-connected static Var generator or absorber whose output is adjusted to exchange capacitive or inductive current so as to maintain or control specific parameters of the electrical power system (typically bus voltage)‖ . SVC is based on thyristors without gate turn-off capability. The adjective‘ static‘ means that, unlike the synchronous compensator, it has no moving primary part. Similar to capacitors, the reactive output of an SVC varies according to the square of the connected bus voltage.

8.2.3 The only SVC in EHV network in the country was constructed by ABB in

year 1992 at 400 kV Kanpur substation of Power Grid Corporation of India Limited. In early nineties, the fault level at this critical station was low and


it was a major load center. 8.2.4 FUNCTIONS OF SVC:- It helps the power system in the following ways : • Improve voltage regulation

Dynamic Mvar Support to the system • Enhancing transmission line power carrying capacity • Improving Dynamic stability of the Integrated Grid • Damping power oscillation on the associated AC lines • Improves & Smoothen Voltage profile 8.3 OPERATING PRINCIPAL AND CHARACTERISTICS OF SVC:- 8.3.1 Two types of Thyristor-controlled elements are used in SVCs:

TSC — Thyristor-switched capacitor TCR — Thyristor- controlled reactor

From a power-frequency point of view they can both be considered as a variable reactance, capacitive or inductive, respectively.

8.3.2 Figure 8.1 shows the diagram of SVC. TCR and TSR are both composed of a shunt-connected reactor controlled by two parallel, reverse-connected thyristors. TCR is controlled with proper firing angle input to operate in a continuous manner, while TSR is controlled without firing angle control which results in a step change in reactance.

8.3.3 TSC shares similar composition and same operational mode as TSR, but the

reactor is replaced by a capacitor. The reactance can only be either fully connected or fully disconnected zero due to the characteristic of capacitor. With different combinations of TCR/TSR, TSC and fixed capacitors, a SVC can meet various requirements to absorb/supply reactive power from/to the transmission line.

Fig 8.1. Static VAR Compensators (SVC):


8.3.4 The SVC at Kanpur consists of two identical Static VAR Compensators (SVCs) – SVC-I and II. It is installed at the voltage level of 10.56 kV bus through 400/10/56 kV coupling transformer.

8.3.5 The operator decides a certain voltage level (Voltage reference) and the SVC

produces sufficient reactive power to maintain the desired voltage level. The two SVCs can be controlled individually or in parallel in so called joint control.

8.3.6 The technical parameters per compensator are as follows: Connection voltage 400 kV, 3 Phase, 50 Hz Rated capacitive generation 140 MVAR Rated inductive generation 140 MVAR The reactive power is 3-phase continuous variable. In voltage control

mode the reference voltage can be adjusted 400 kV +5-5% TCR 1 and 2 rated power 95 MVAR TSC 1 rated power 90 MVAR 7th harmonic filter bank 10 MVAR 5th harmonic filter bank 40 MVAR

8.3.7 Some of the control functions not influenced by operator actions are given

below:- 8.3.8 SYSTEM UNDER VOLTAGE SUPERVISON :

The SVC control system provides the following automatic control functions in case of under voltage on the 400 kV bus.

The SVC output is controlled to 0 Mvar at undervoltage but returns to normal operation if the voltage comes back within 1 second.

The SVC regulator is blocked if the voltage remains low after 1 second. However, the SVC returns to normal operation if the voltage comes back within 2.5 seconds.

The SVC is tripped if the voltage remains low after 2.5 seconds. However, the SVC is automatically started if the voltage returns within 5 minutes.

8.3.9 SYSTEM FREQUENCY SUPERVISION : Abnormal system frequencies have the following impact on SVC operation :

47.5 – 52 Hz Normal Operation 42-47.5/ 52-53 Hz TSC/TCR block after 0.3-2 seconds <42/ >53 Hz SVC Trip

8.3.10 SVC configuration at maximum & minimum output

The voltage on the connecting 400 kV bus is controlled by means of two thyristor controlled reactor (TCRs) and one thyristor switched capacitor TSC). SVC outpur can be any value between – 140 MVAR to + 140 MVAR. SVC configuration at maximum and minimum outputs is as tabulated below:


SVC Elements MVAR rating Maximum

Output Minimum Output

7th Harmonic Filter Bank (Capacitor) 10 10 10 5th Harmonic Filter Bank (Capacitor) 40 40 40 Thyristor Switched Capacitor 90 90 Thyristor Controlled Reactor-1 -95 -95 Thyristor Controlled Reactor-2 -95 -95 Total -50 140 -140

SVC configuration at Maximum & Minimum output 8.3.11 DIFFERENT MODES OF SVC OPERATION:

a) Automatic voltage Control Mode: In NORMAL OPERATION the SVC is

voltage controlled. In this mode the desired Voltage reference is set and the calculated value of the SVC current is fed to the voltage regulator. This will cause a load dependent SVC voltage a slope control. Vref can be set at 400 kV +5% of -5%. Typical SVC characteristics with V ref 400 kV and slope 3%, 4%, 5% is shown at plot-1 & plot-2 and with V ref 390 kV and slope 3%, 4%, 5% is shown at plot-3 and plot-4.

b) Manual VAR control mode: In Manual mode the SVC is Mvar – controlled. The desired MVAR level is set.

c) Forced Manual Mode: If the control system loses the voltage response signal the compensator is automatically switched to MANUAL mode. The MVAR outpur at the time of switching will remain. The Mvar output can be adjusted, if needed, in MANUAL mode.

d) No Bus Mode (Emergency Mode) : In case of a fault in the var control computer the system is transferred to NO BUS mode. In this mode the TCR Mvar output is controlled and the TSC steps can be switched in an out.

8.3.12 Susceptance (B) control :

a) In addition to the voltage and var control modes described above the operator can order the susceptance control function. Voltage control mode allows SVC to reach its reactive power limits too frequently in order to maintain Vref. This may leave with no scope for dynamic compensation in the event of disturbance.

b) The slow susceptance control corrects the voltage reference in order to

maintain a fixed reactive power generation under steady state conditions This function can be ordered ON and OFF. In this mode the var output is

fixed within the prescribed dead band presently set at +2% and -3% of 400


kV. The var output in this band can be +/-40% of 140 MVAR. SVC at Kanpur shall be normally runs in this mode, primarily due to following reasons. • Substantial reduction in requirement of reactive power. • Prevention of SVC operation at 100% capacity in normal conditions.

• Maintains reserves to support under disturbance.

Plot 1: SVC characteristics with V ref 400 kV in Voltage Control Mode

SVC Characterstics in Voltage Control Mode

-150

-100

-50

0

50

100

150

380 384 388 392 396 400 404 408 412 416 420

Bus Voltage in kV

SV

C o

utp

ut

in M

VA

R

Setting:

Mode: Voltage Control

V ref: 400 kV

Slope: 3% or 11.67 MVAR per kV

4% or 08.75 MVAR per kV


Slope 5 %

Slope 3 %

Slope 4 %

Plot 2: SVC characteristics with V ref 390 kV in Voltage Control Mode

SVC Characterstics in Voltage Control Mode

-150

-100

-50

0

50

100

150

380 384 388 392 396 400 404 408 412 416 420

Bus Voltage in kV

SV

C o

utp

ut

in M

VA

R

Setting:

Mode: Voltage Control

V ref: 390 kV

Slope: 3% or 11.67 MVAR per kV



Slope 5 %

Slope 3 %

Slope 4 %


Plot 3 : SVC Responce to Fault on 400 kV Agra Muradnagar on 6-7-05

-291 MVAR

238 MVAR

-350

-250

-150

-50

50

150

250

350

360

370

380

390

400

410

420

1:0

0:0

0 A

M

1:0

5:4

0 A

M

1:1

1:2

0 A

M

1:1

7:0

0 A

M

1:2

2:4

0 A

M

1:2

8:2

0 A

M

1:3

4:0

0 A

M

1:3

9:4

0 A

M

1:4

5:2

0 A

M

1:5

1:0

0 A

M

1:5

6:4

0 A

M

2:0

2:2

0 A

M

2:0

8:0

0 A

M

2:1

3:4

0 A

M

2:1

9:2

0 A

M

2:2

5:0

0 A

M

2:3

0:4

0 A

M

2:3

6:2

0 A

M

2:4

2:0

0 A

M

2:4

7:4

0 A

M

2:5

3:2

0 A

M

2:5

9:0

0 A

M

3:0

4:4

0 A

M

3:1

0:2

0 A

M

3:1

6:0

0 A

M

3:2

1:4

0 A

M

3:2

7:2

0 A

M

3:3

3:0

0 A

M

3:3

8:4

0 A

M

3:4

4:2

0 A

M

3:5

0:0

0 A

M

3:5

5:4

0 A

M

SV

C O

utp

ut in

MV

AR

Vo

lta

ge

in k

V

SVC Response during 63 minute fault feeding on 400 kV Agra -Muradnagar fault on 6th July 2005

SVCs at Kanpur came into action providing a dynamic support of 529 MVAR (recorded at NRLDC)

Output of SVC s changed from 291 MVAR reactive to 238 MVAR capacitive. (recorded at NRLDC)

Plot 4 : SVC Response during fault at Rihand STPS on 1st June 2010


8.2.13 CONVERTER-BASED COMPENSATOR :-

a) Static Synchronous Compensator (STATCOM) is one of the key Converter-based Compensators which are usually based on the voltage source inverter (VSI) or current source inverter (CSI), as shown in Figure 8.2.

b) Unlike SVC, STATCOM controls the output current independently of the

AC system voltage, while the DC side voltage is automatically maintained to serve as a voltage source. Mostly, STATCOM is designed based on the VSI (Voltage Source Inverter).

Fig 8.2. STATCOM topologies: (a) STATCOM based on VSI and CSI

(b) STATCOM with storage.

c) Compared with SVC, the topology of a STATCOM is more complicated. The switching device of a VSI is usually a gate turn-off device paralleled by a reverse diode; this function endows the VSI advanced controllability. Various combinations of the switching devices and appropriate topology make it possible for a STATCOM to vary the AC output voltage in both magnitude and phase. Also, the combination of STATCOM with a different

storage device or power source (as shown in Figure 8.2) endows the STATCOM the ability to control the real power output.

d) STATCOM has much better dynamic performance than conventional

reactive power compensators like SVC. The gate turn-off ability shortens the dynamic response time from several utility period cycles to a portion of a period cycle. STATCOM is also much faster in improving the transient response than a SVC. This advantage also brings higher reliability and larger operating range.

8.2.14 SERIES-CONNECTED CONTROLLERS:- As shunt-connected controllers, series-connected FACTS controllers can also be divided into either impedance type or converter type. The former


includes Thyristor-Switched Series Capacitor (TSSC), Thyristor- Controlled Series Capacitor (TCSC), Thyristor- Switched Series Reactor, and Thyristor-Controlled Series Reactor. The latter, based on VSI, is usually in the Compensator (SSSC). The composition and operation of different types are similar to the operation of

the shunt connected peers. Figure shows the diagrams of various series- connected controllers.

Fig 8.3. Series-connected FACTS controllers: (a) TCSR and TSSR; (b) TSSC; (c) SSSC


9. Generator reactive power capability

9.1 A generator‘s output capabilities depend on the thermal limits of various parts of the generator and on system stability limits. Thermal limits are physical limits of materials such as copper, iron and insulation, if the generator overheats, insulation begins to degrade and over time this could result in equipment damage. Increasingly real power output of a generator heats up the armature. Increasing reactive power output heats up the field windings and the armature. 9.2 Power Generators shall be able to supply or absorb reactive power

according to the reactive power capability curve that is defined in connection agreement and shall perform yearly inspection to ensure that generators can perform according to the reactive power capability curve.

9.3 To supply reactive power, the generator must increase the magnetic field to raise the voltage it is supplying to the power system; this means increasing the current in the filed windings, which is limited by the thermal properties of the metal and insulation. The field current is supplied by the generator exciter, which is a DC power supply connected to the generator. The field current can be quickly adjusted by automatic control or with a dial to change the reactive power supplied or consumed by the generator. 9.4 At any given field setting, the generator has a specific terminal voltage it is attempting to hold. If the system voltage declines, the generator will inject reactive power into the power system, tending to raise system voltage. If the system voltage rises, the reactive output of the generator will drop and ultimately reactive power will flow into the generator, tending to lower system voltage. 9.5 The voltage regulator will accentuate this behavior by driving the field current in the appropriate direction to obtain the desired system voltage. Because most of the reactive limits are thermal limits associated with large pieces of equipment, significant short-term extra reactive-power

capability usually exists.

9.6 Power-system stabilizers also control generator field current and reactive-power output in response to oscillations on the power system. This function is a part of the network-stability ancillary service.

9.7 Stability limits are determined by the ability of the power system to accept delivery of power from the connected generator under a defined set of system conditions including recognized contingencies. All generators connected to a power system operate at the same electrical frequency; if a generator loses synchronism with the rest of the system, it will trip offline


to protect itself. 9.8 Capacitors supply reactive power and have leading power factors, while inductors consume reactive power and have lagging power factors. The convention for generators is the reverse. When the generator is supplying reactive power, it has a lagging power factor and its mode of operation is

referred to as overexcited. When a generator consumes reactive power, it has a leading power factor region and is under-excited. 9.9 The capability-set limits are thermal limits for different parts of the generator, if the generator output approaches these limits, an alarm will notify the generator operator of the problem; if the operator does not bring the generator back to a safe operating point, the generator‘s protection scheme (relays, circuit breakers, fuses) will operate, resulting in disconnection of the generator from the network; finally, if the protection equipment fails and the operator does not act in time, the generator will overheat, potentially causing equipment damage. Because generators are expensive, generator operators generally will not operate the generator in a way that risks damaging the equipment and losing revenue during repair. 9.10 The ability of a generator to provide reactive support depends on its real-

power production which is represented in the form of generator capability curve or D - curve. Figure 9.1 shows the combined limits on real and reactive production for a typical generator. Like most electric equipment, generators are limited by their current-carrying capability. Near rated voltage, this capability becomes an MVA limit for the armature of the generator rather than a MW limitation, shown as the armature heating limit in the Figure.

Fig 9.1 GENERATOR CAPABILITY CURVE or D CURVE


9.11 At the edges of the D-curve, the opportunity cost of extending generator real

or reactive power supply amounts to the millions of rupees that would be needed to replace damaged generator equipment and lost revenue during repair. The characteristics of the generator step-up transformer that connects

the generator to the electric transmission system, as well as operational policies of the transmission system, may impose further limits on generator output.

9.12 Generator capability may be extended by the coolant used in the generator. A more efficient coolant allows the generator to dissipate more heat, thereby extending thermal limits. Most large generators are cooled with hydrogen; increasing the hydrogen pressure cools the generator equipment more effectively, increasing the generator‘s capability. 9.13 SYNCHRONOUS CONDENSERS:

9.13.1. Synchronous condenser is another reactive power device, traditionally in

use since 1920s. A synchronous Condenser is a synchronous machine running without a prime mover or a mechanical load. Like generators, they can be over-exited or under-exited by varying their field current in order to generate or absorb reactive power, synchronous condensers can continuously regulate reactive power to ensure steady transmission voltage, under varying load conditions.

9.13.2. They are especially suited for emergency voltage control under loss of load, generation or transmission, because of their fast short-time response. Synchronous condensers provide necessary reactive power even exceeding their rating for short duration, to arrest voltage collapse and to improve system stability. It draws a small amount of active power (about 3%) from the power system to supply losses.

9.13.3. Synchronous machines that are designed exclusively to provide reactive

support are called synchronous condensers. Synchronous condensers have all of the response speed and controllability advantages of generators without the need to construct the rest of the power plant (e.g., fuel-handling equipment and boilers). Because they are rotating machines with moving parts and auxiliary systems, they may require significantly more maintenance than static alternatives. They also consume real power equal to about 3% of the machine‘s reactive-power rating. That is, a 50- MVAR synchronous condenser requires about 1.5 MW of real power. 9.14 Synonymous terms are synchronous compensator and synchronous phase

modifier. The synchronous compensator is the traditional means for Continuous control of reactive power. Synchronous compensators are used


in transmission systems: at the receiving end of long transmissions, in important substations and in conjunction with HVDC inverter stations. Small synchronous compensators have also been installed in high-power industrial networks of steel mills; few of these are in use today. Synchronous compensators in use range in size from a few MVA up to

hundreds of MVA. 9.15 Some hydro/gas generators can operate as synchronous condensers. Such gas based units are often equipped with clutches which can be used to disconnect the turbine from the generator when active power is not required from them. In case of hydro, water supply is blocked and units run with loads of only air friction

9.16 A synchronous Compensator has several advantages over static compensators. Synchronous compensators contribute to system short circuit capacity. Their reactive power production is not affected by the system voltage. During power swings (electro mechanical oscillations) there is an exchange of kinetic energy between a synchronous condenser and the power system. 9.17 During such power swings, a synchronous condenser can supply a large

amount of reactive power, perhaps twice its continuous rating. Unlike other forms of shunt compensation, it has an internal voltage source and is better to cope with the low voltage conditions. Because of their high purchase and operating costs, they have been largely superseded by static var compensators.

9.17 In recent years the synchronous compensator has been practically ruled out

by the SVC, in the case of new installations, due to benefits in cost performance and reliability of the latter. One exception is HVDC inverter stations, in cases where the short-circuit capacity has to be increased. The synchronous compensators can do this, but not the SVC.

9.18 Comparison between Synchronous Condenser and shunt capacitor is explained in the below table :-

Sl.No Synchronous condenser Shunt capacitor

1. Synchronous condenser can supply kVAR equal to its rating and can absorb up to 100% of its KVA rating

Shunt capacitor should be associated with a reactor to give that performance

2. This has fine control with AVR This operates in steps


Sl.No Synchronous condenser Shunt capacitor

3. The output is not limited by the system voltage condition. This gives out its full capacity even when system voltage decreases

The capacitor output is proportional to V2 of the system. Hence its performance decreases under low voltage conditions

4. For short periods the synchronous condenser can supply KVAR in excess of its rating at nominal voltage

The capacitor can not supply more than its capacity at nominal voltage. Its output is proportional to V2.

5. The full load losses are above 3% of its capacity

The capacitor losses are about 0.2%

6. These can not be economically deployed at several locations in distribution

The capacitor banks can be deployed at several locations economically in distribution

7. The synchronous condenser ratings can not be modular

The capacitors are modular. They can be deployed as and when system requirements change

8. A failure in the synchronous condenser can remove the entire unit ability to produce KVAR. However failures are rare in synchronous condensers compared to capacitors

A failure of a single fused unit in a bank of capacitors affects only that unit and does not affect the entire bank

9. They add to the short circuit current of a system and therefore increase the size of (11kV etc.) breakers in the neighbour-hood.

The capacitors do not increase the short circuit capacity of the system, as their output is proportional to V2

10. This is a rotating device. Hence the O&M problems are more

These are static and simple devices. Hence O&M problems are negligible

9.19 As per planning philosophy and general guidelines in the Manual on Transmission planning criteria issued by CEA (MOP, India), Thermal / Nuclear Generating Units shall normally not run at leading power factor. However for the purpose of charging unit may be allowed to operate at leading power factor as per the respective capability curve. 9.20 List of synchronous condenser at all India level is given in Annexure 12.


10.Reactive power management and renewable energy

10.1 INTRODUCTION

10..1 Due to depleting nature of these reserves, efforts are on worldwide to ensure energy security through alternate technologies for electric power generation. Global demand for energy is increasing at a breathtaking pace, which will require significant investment in new power generation capacity and grid infrastructure. Wind energy, however, is a massive indigenous power source which is available virtually everywhere in the world. There are no fuel costs, no geo-political risk and no supply import dependency.

10.2 IEGC recommends the following requirements on renewables.

1. As per IEGC Section 5.2 System Security Aspects :-

―5.2 System Security Aspects

(u) Special requirements for Solar/ wind generators (i) SLDC/RLDC may direct a wind farm to curtail its VAr drawl/injection in case the security of grid or safety of any equipment or personnel is endangered. (ii) During the wind generator start-up, the wind generator shall ensure that the reactive power drawl (inrush currents in case of induction generators shall not affect the grid performance.‖ 10.3 RE Technologies :

10.3.1 Various types of RE :

1. Wind (On-shore, Off shore)

2. Solar (Solar PhotoVoltaic, Solar Thermal)

3. Micro Hydro (with Pondage , without Pondage )

4. Biomass (Bagasse, other bio-mass material like rice husk, cotton

stalk, mustard stalk, groundnut shell, coconut fronds, waste cotton stalks, bark, roots of trees, cane trash, arecanut shells, Prosopis juliflora, poultry litter)

5. Non fossil fuel based co generation

Wind is most predominantly used technology world-wise, hence we focus more on it in this discussion.


10.4 Technology of Wind Generators

Wind power systems convert the movement of air into electricity by means

of a rotating turbine and a generator. There are two types of Wind generators viz On- and off-shore. In the beginning, generators of a few kW typically 250kW were manufactured. Nowadays with advancement in technology very large wind turbines (up to 5 MW) are in operation. Offshore windfarms are expected to have higher load factors.

10.5 Types of Wind Generators :

1. Induction (Type-1)

a squirrel cage induction generator that is driven through a gearbox. It operates within a very narrow speed range and is now obsolete. Generally fixed speed is achieved through a gear box.

2. Variable-slip Induction Generator (Type-2) It includes a wound rotor and a mechanism to quickly control the current in the rotor and results in better response to fast dynamic events.

3. Doubly Fed Induction Generator (DFIG) (Type-3) The turbine-generator power output passes through two components

1) about 70% through a mechanism that produces a variable-frequency current in the rotor circuit 2) AC-DC-AC power converters The first mechanism enables the wind turbine generator to operate at a variable speed typically about 2:1 range from max to min speed). This improves the power conversion efficiency and controllability of the wind turbine generator. The AC-DC-AC power converters need only be rated to carry a fraction, typically 30%, of the total wind turbine-generator power output.

4. Full conversion Wind Turbine-Generator (Type-4) The entire turbine power output through an AC-DC-AC power electronic converter system. the output current of a Type 4 wind turbine generators can be electronically modulated to zero; thereby limiting its short-circuiting current contribution and reducing the short-circuit duty of standard protection equipment. It has a comparable inertial response/ performance to a conventional generator.

Out of the above, type 1 and 2 are now obsolete and type 3 & 4 are being more popular.


10.6 Variable generation plants are often located in remote areas of the network where the short circuit level is weak and, as a result, problems such as under-/over-voltages, harmonics or voltage unbalances may be observed.

10.7 Wind Farm : A group of wind generators located in an area connected to a

common pooling station is called a Wind Farm. Its aggregated capacity ranges from 25-50MW.

10.8 Reactive requirement:

a) The type-1 and Type-2 machines being induction generators can not participate in voltage regulation and require switched shunt capacitor banks for reactive compensation.

b) Due to variable speed, WTG depend on AC-DC-AC convertors which will provide an asynchronous link between the WTG and Grid. These power electronic devices generally have inherent control of reactive power and can participate in voltage regulation. Due to restriction on drawl of reactive power from Grid, a combination of switched capacitor banks and/or power electronic transmission technologies such as SVC/STATCOM are provided for Reactive support and power factor control.

c) The reactive compensation system of wind farms shall be such that Wind farms shall maintain power factor between 0.95 lagging and 0.95 leading at the connection point.

10.9 CIGRE 293 report of Working Group C1.3 on Electric Power System Planning with the Uncertainty of Wind generation studied the following : Plant tolerance to voltage and frequency variation

plant capability regards

tolerance to system faults and performance during and after faults

reactive power

active power management

power quality

control capability to manage

power ramping up

response

voltage and power factor control


10.10 The Wind generating machines shall have the operating region as shown in Figure given below during system faults. Wind farms can be disconnected if the operating point falls below the line in the below Figure 10.1 .

FIGURE 10.1 Fault Ride through characteristics

10.11 Wind farms connected to high voltage transmission system must stay connected when a voltage dip occurs in the grid, otherwise, the sudden disconnection of a large amount of wind power may contribute to the voltage dip, with adverse consequences. Wind farms must remain connected when the voltage dip profile is above the line shown in the figure. The per unit voltage at the point of connection to the grid is shown in the vertical axis and the duration (seconds) of the fault in the horizontal axis. This code requires Fault Ride-Through (FRT) capability during voltage drops in Transmission System to 15% of nominal voltage during 300 ms with recovery up to 80% of nominal voltage after 3 sec, with the slope shown in figure given above.

10.12 The wind generating machines shall be equipped with fault ride through capability. During a Fault Ride through, the Reactive power drawl from Grid shall be minimum and active power generation shall be in proportion to the retained grid voltage. They should have the capability to withstand repetitive faults.


11.Ready Reckoner

1. Change in voltage at a bus

∆ V = ∆Q . V Fault Level of the Bus

Units: ∆ V & V (kV), ∆ Q (MVAR), Fault Level (MVA)

2. Fault contribution at HT bus of Unit Transformer:

Sl No. Unit Size(MW) Type 3 Φ MVA Contribution 1 60 Hydro 280

2 120 Thermal 490

3 210 Thermal 735

4 500 Thermal 1800

Thumb Rule: Short circuit level contribution of a generating unit is 3-4 times its MVA rating.

3. Line Charging MVAR:

Sl. No. Voltage Level

(kV) Conductor Type

Line Charging MVAR/100 km/ckt

1 132 Panther 5

2 220 Zebra 13.5

3 400 Twin Moose 55.5

4 400 Quad Moose 74

5 400 Quad Bersimis (Delhi ring) 74.6

6 765 at 400 Triple Snow Bird 65.6

6 765 Quad Bersimis 291

Source: CEA: Manual on Transmission Planning Criterion, 1994

4. Line Current

Sl No. Voltage Level (kV) Ampere/MVA

1 132 4.4

2 220 2.6

3 400 1.4

5. Voltage rise at receiving end of uncompensated line

Sl No. Voltage Level(kV)

Conductor Type (Single circuit)

Voltage Rise (kV) per 100km

1 132 Panther 0.75

2 220 Zebra 1.5

3 400 Twin Moose 3


6. Rated breaking Current Capability of Switch Gear

Source: CEA: Manual on Transmission Planning Criterion, 1994

7. MW vs. Current (ampere)

Sl. No. Voltage Level (kV) MW

1 400 =2/3 * current (amp)

2 220 =1/3 * current (amp)

3 132 =1/4 * current (amp)

8. Impact of 1000 amp flow on a 100 km Ling 400 kV Line (Unity p.f.)

a) I2 X loss -100 MVAR

b) I2 R loss -10 MW

c) Potential drop (Vs-Vr) -3.3 kV

9. Line Charging Guidelines:

In case, line reactor is available at only one end, it is preferable to charge the line from the end without reactor and synchronize at the end with reactor. If the line is to be opened, open from the end where line reactor is available.

Thumb rule is “synchronize or open from the end where line reactor is available”.

The line should be charged from the end with higher fault level (3 phase short circuit MVA) in order to limit the over voltage at charging end.

If two buses have almost same short circuit level (3-ph) and neither is a generation station, charge the line from the bus with lower voltage. At the charging end, all measures should be taken to control high voltage

a) Bus reactors may be taken in to service b) Generators at the charging end may be operated at reduced voltage (less than 1 p.u.)

and in lagging power factor mode c) Suitable measures may be taken to avoid large frequency variations d) Loads may be taken into service in small steps.

10. Line Equivalent of a Transformer:

Conductor Type

500 MVA Transformer is equivalent to transmission line (in km)

315 MVA Transformer is equivalent

to transmission line (in km)

250 MVA Transformer is equivalent

to transmission line (in km)

765 KV Quad Bersimis 559 887 1117

400 kV Quad Bersimis 153 242 305

400 kV Quad Moose Tala 159 253 319

400 kV Triple Snowbird 145 230 290

400 kV Twin Moose 120 191 241

220 kV Zebra 30 48 61

Sl No. Voltage Level (kV) Kilo ampere 1 765 40

2 400 40

3 220 31.5/40

4 132 25/31


12. References

12.1 Indian Electricity Grid Code, India, May 2010

12.2 The Central Electricity Authority (Technical Standard for Connectivity to

the Grid) Regulations 2007.

12.3 Manual on Transmission Planning Criteria, CEA, Govt of India, June 1994

12.4 Principles of efficient and reliable reactive power supply and consumption,

staff report, FERC, Docket No. AD05-1-000, February 4, 2005

12.5 Power System Stability and Control by P. Kundur, Tata McGraw Hill, New

Delhi, 2007

12.6 Reactive Power Control in Electric Systems, Edited by Timothy j. e. Miller ,

Wiley- Interscience

12.7 Power system Restoration : Methodologies and Implementation Strategy By

M.M. Adibi, IEEE Press

12.8 Modern Power Station Practice, System Operation Volume – L, 3rd Edition, British Electricity International. 12.9 Reactive Capability Limitations of Synchronous Machine, M.M. Adibi et

al.,(IEEE Transactions on Power System, February 1994)

12.10 Reactive Power Management and Voltage Control in Northern Region.

12.11 Reactive Power Management and Voltage Control in Southern Region.

12.12 Document on Reactive Power by Western Region.

12.13 Reactive Power Management and Voltage Control in Eastern Region.

12.14 Reactive Power Management and Voltage Control in North Eastern Region.

12.15 Operating procedure manual of NLDC

ANNEXURE 1

INTER REGIONAL LINES 400kV and above

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor

(Yes=1, No=-1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of

the line

Remarks

1 400 ALLAHABAD SASARAM 1 D/C 212 Twin Moose 0.00 57.14 1 515 0.555 117.7

2 400 BALIA BIHARSHARIFF 1 D/C 242 Quad Moose 45.35 -1 0.00 687 0.740 179.1

3 400 BALIA BIHARSHARIFF 2 D/C 242 Quad Moose 45.35 -1 0.00 687 0.740 179.1

4 400 BALIA PATNA 1 D/C 198 Quad Moose 0.00 0.00 687 0.740 146.5

5 400 BALIA PATNA 2 D/C 198 Quad Moose 0.00 0.00 687 0.740 146.5

6 400 BALIA BARH 1 D/C 244 Quad Moose 0.00 0.00 687 0.740 180.6

7 400 BALIA BARH 2 D/C 244 Quad Moose 0.00 0.00 687 0.740 180.6

8 400 GORAKHPUR-PG MUZAFFARPUR 1 D/C 261 Quad Moose 0.00 57.14 1 687 0.740 193.1

9 400 GORAKHPUR-PG MUZAFFARPUR 2 D/C 261 Quad Moose 0.00 57.14 1 687 0.740 193.1

10 400 SARNATH SASARAM 1 D/C 76 Twin Moose 0.00 57.14 1 515 0.555 42.2

11 765 AGRA GWALIOR 1 S/C 129 Quad Bersimis 0.00 0.00 633 0.730 94.2

12 765 AGRA GWALIOR 2 S/C 128 Quad Bersimis 0.00 0.00 633 0.730 93.4

13 400 BHINMAL ZERDA 1 S/C 143 Twin Moose 0.00 45.35 -1 515 0.555 79.3

14 400 KANKROLI ZERDA 1 S/C 234 Twin Moose 45.35 -1 45.35 -1 515 0.555 129.7

15 400 RAIGARH(PG) ROURKELA (PG) 1 D/C 212 Twin Moose 0.00 57.14 515 0.555 117.7



18 400 STERLITE RAIGARH 1 D/C 114 Twin Moose 0.00 0.00 515 0.555 63.3

19 400 RANCHI SIPAT 1 D/C 406 Twin Moose 72.56 1 0.00 515 0.555 225.3

20 400 RANCHI SIPAT 2 D/C 406 Twin Moose 72.56 1 0.00 515 0.555 225.3

21 400 JEYPORE (PG) GAZUWAKA (PG-SR) 1 D/C 220 Twin Moose 0.00 72.56 -1 515 0.555 122.1

22 400 JEYPORE (PG) GAZUWAKA (PG-SR) 2 D/C 220 Twin Moose 0.00 72.56 -1 515 0.555 122.1

23 400 BINAGURI (PG) BONGAIGAON (NER) 1 D/C 216 Twin Moose 57.14 -1 57.14 -1 515 0.555 119.9

24 400 BINAGURI (PG) BONGAIGAON (NER) 2 D/C 216 Twin Moose 0.00 57.14 -1 515 0.555 119.9

400KV AND ABOVE AC LINES

*Series

compensated line

(30%) + TCSC

INTER REGIONAL LINES 400KV and above

NLDC,2012 REACTIVE POWER MANAGEMENT -a resource handbook 1 OF 1

ANNEXURE 2

All India Reactive power compensation details for the transmission system

Sl.

No

Region

(A)

NO of 400 &

above lines

(B)

CIRCUIT.

KMS

(C)

Total Mvar

Generated

by the line

@ 1.0 p.u

voltage

(D)

No of line

Reactors

(E)

line

Reactors

Mvar

(F)

No of Bus

Reactors

(G)

Bus

Reactors

Mvar

(H)

%

Compensation

Line Raectors

(F/D)

% Compensation

Bus Reactors

(H/D)

Total

Compensation

Mvar

(F+H)

% Compensation

Line + Bus reactor

(F+H)

*

1Inter

Regional24 5246 3305.9 18 1200.00 36.30 0.00 1200 36

2 Northern 215 29335 16886.1 112 6684.52 50 3301.00 39.59 19.55 9986 59

3 Western 216 36060 22077.8 100 5869.00 52 3041.00 26.58 13.77 8910 40

4 Southern 147 19267 10825.2 60 3323.00 28 1559.00 30.70 14.40 4882 45

5 Eastern 74 10871 6367.4 50 2318.00 25 1417.00 36.40 22.25 3735 59

6North

Eastern6 1103 612.1 8 426.00 4 200.00 69.59 32.67 626 102

TOTAL 682 101882 60074.4 348 19820.52 159 9518 32.99 15.84 29339 49

Estimation of losses on account of reators in the system:

1)

2)

* It may be noted that the reactor rating is generally @1.05 p.u. voltage. So ideally col. 'D' would be 1.1025 times the value mentioned if we take 1.05 p.u. voltage.

Approximate loss = 29339 MVAR/550 = 54 MW ( 36MW on account of line reactors and 18 MW on account of bus reactor)

`

ALL INDIA REACTIVE POWER COMPENSATION DETAILS

As on 31-12-2011

Typical X/R ratio of bus reactos = 550

NLDC, 2012 REACTIVE POWER MANAGEMENT-a resource handbook1 OF 1

ANNEXURE 3

ESTIMATED MVAR RELIEF AVAILABLE WHEN LINE IS OPENED

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor (Yes=1,

No=-1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of

the line

MVAR relief

available

when line is

opened

MVAR relief

available when line

is opened & Line

Reactor is used as

Bus Reactor

Remarks

1 765 AGRA GWALIOR 1 S/C 129 Quad Bersimis 0.00 0.00 633 0.730 94.2 94.17 94.17

2 765 AGRA GWALIOR 2 S/C 128 Quad Bersimis 0.00 0.00 633 0.730 93.4 93.44 93.44

3 400 BHINMAL ZERDA 1 S/C 143 Twin Moose 0.00 45.35 -1 515 0.555 79.3 33.90 33.90

4 400 KANKROLI ZERDA 1 S/C 234 Twin Moose 45.35 -1 45.35 -1 515 0.555 129.7 39.00 39.00

5 400 ALLAHABAD SASARAM 1 D/C 212 Twin Moose 0.00 57.14 -1 515 0.555 117.7 60.52 60.52

6 400 BALIA BIHARSHARIFF 1 D/C 242 Quad Moose 45.35 -1 0.00 687 0.740 179.1 133.73 133.73

7 400 BALIA BIHARSHARIFF 2 D/C 242 Quad Moose 45.35 -1 0.00 687 0.740 179.1 133.73 133.73

8 400 BALIA PATNA 1 D/C 198 Quad Moose 0.00 0.00 687 0.740 146.5 146.52 146.52

9 400 BALIA PATNA 2 D/C 198 Quad Moose 0.00 0.00 687 0.740 146.5 146.52 146.52

10 400 BALIA BARH 1 D/C 244 Quad Moose 0.00 0.00 687 0.740 180.6 180.56 180.56

11 400 BALIA BARH 2 D/C 244 Quad Moose 0.00 0.00 687 0.740 180.6 180.56 180.56

12 400 GORAKHPUR-PG MUZAFFARPUR 1 D/C 261 Quad Moose 0.00 57.14 -1 687 0.740 193.1 136.00 136.00

13 400 GORAKHPUR-PG MUZAFFARPUR 2 D/C 261 Quad Moose 0.00 57.14 -1 687 0.740 193.1 136.00 136.00

14 400 SARNATH SASARAM 1 D/C 76 Twin Moose 0.00 57.14 -1 515 0.555 42.2 -14.96 -14.96

15 400 RAIGARH(PG) ROURKELA (PG) 1 D/C 212 Twin Moose 0.00 57.14 515 0.555 117.7 60.52 117.66



18 400 STERLITE RAIGARH 1 D/C 114 Twin Moose 0.00 0.00 515 0.555 63.3 63.27 63.27

19 400 RANCHI SIPAT 1 D/C 406 Twin Moose 72.56 1 0.00 515 0.555 225.3 152.77 225.33

20 400 RANCHI SIPAT 2 D/C 406 Twin Moose 72.56 1 0.00 515 0.555 225.3 152.77 225.33

21 400 JEYPORE (PG) GAJUWAKAKA (PG-SR) 1 D/C 220 Twin Moose 0.00 72.56 -1 515 0.555 122.1 49.54 49.54

22 400 JEYPORE (PG) GAJUWAKAKA (PG-SR) 2 D/C 220 Twin Moose 0.00 72.56 -1 515 0.555 122.1 49.54 49.54

23 400 BINAGURI (PG) BONGAIGAON (NER) 1 D/C 216 Twin Moose 57.14 -1 57.14 -1 515 0.555 119.9 5.59 5.59

24 400 BINAGURI (PG) BONGAIGAON (NER) 2 D/C 216 Twin Moose 0.00 57.14 -1 515 0.555 119.9 62.74 62.74

5246 338.3 693.0 3305.9 2274.6 2534.0 TOTAL

INTER REGIONAL LINK

NLDC, 2012 REACTIVE POWER MANAGEMENT-a resource handbook1 OF 26

ANNEXURE 3


NORTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt.

Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used

as Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

Remarks

1 400 Abdullapur Bawana 1 D/C 167 Triple Snowbird 0.00 0.00 605 0.656 109.3 109.3 109.3

2 400 Abdullapur Bawana 2 D/C 167 Triple Snowbird 0.00 0.00 605 0.656 109.3 109.3 109.3

3 400 Abdullapur Sonepat 1 D/C 150 Triple Snowbird 0.00 0.00 605 0.656 98.4 98.4 98.4

4 400 Abdullapur Sonepat 2 D/C 150 Triple Snowbird 0.00 0.00 605 0.656 98.4 98.4 98.4

5 400 Agra Agra(UP) 1 D/C 30 Twin Moose 0.00 0.00 515 0.555 16.7 16.7 16.7

6 400 Agra Agra(UP) 2 D/C 30 Twin Moose 0.00 0.00 515 0.555 16.7 16.7 16.7

7 400 Agra Ballabgarh 1 S/C 181 Twin Moose 45.35 -1 45.35 -1 515 0.555 100.5 9.8 9.8

8 400 Agra Bassi 1 S/C 211 Twin Moose 45.35 -1 45.35 -1 515 0.555 117.3 26.6 26.6



11 400 Agra Bhiwadi 1 D/C 209 Twin Moose 45.35 -1 0.00 515 0.555 116.0 70.6 70.6

12 400 Agra Bhiwadi 2 D/C 210 Twin Moose 0.00 0.00 515 0.555 116.3 116.3 116.3

13 400 Allahabad Kanpur 1 S/C 225 Twin Moose 0.00 0.00 515 0.555 124.9 124.9 124.9

14 400 Allahabad Fatehpur 3 S/C 155 Twin Moose 0.00 0.00 515 0.555 86.0 86.0 86.0

15 400 Allahabad Mainpuri 1 D/C 363 Twin Moose 45.35 -1 72.56 1 515 0.555 201.7 83.8 156.3

*Series

compensated line

(Degree of comp-

40%)16 400 Allahabad Mainpuri 2 D/C 363 Twin Moose 45.35 -1 72.56 1 515 0.555 201.7 83.8 156.3

*Series

compensated line

(Degree of comp-17 400 Amritsar Amritsar 1 S/C 60 Twin Moose 0.00 0.00 515 0.555 33.1 33.1 33.1

18 400 Auraiya Agra 1 D/C 166 Twin Moose 0.00 45.35 -1 515 0.555 92.0 46.7 46.7

19 400 Auraiya Agra 2 D/C 166 Twin Moose 0.00 45.35 -1 515 0.555 92.0 46.7 46.7

20 400 Bahadurgarh Bhiwani 1 D/C 84 Twin Moose 0.00 0.00 515 0.555 46.8 46.8 46.8

21 400 BahadurgarhMahindergarh

HVDC1 D/C 42 Twin Moose 0.00 0.00 515 0.555 23.3 23.3 23.3

22 400 BhiwaniMahindergarh

HVDC1 D/C 42 Twin Moose 0.00 0.00 515 0.555 23.3 23.3 23.3

23 400 Bahadurgarh Sonepat 1 D/C 52 Triple Snowbird 0.00 0.00 605 0.656 34.1 34.1 34.1

24 400 Bahadurgarh Sonepat 2 D/C 52 Triple Snowbird 0.00 0.00 605 0.656 34.1 34.1 34.1

25 400 Balia Lucknow PG 1 D/C 316 Twin Moose 57.14 -1 57.14 -1 515 0.555 175.5 61.2 61.2

*Series

compensated line

(Degree of comp-

40%)

26 400 Balia Lucknow PG 2 D/C 316 Twin Moose 57.14 -1 45.35 -1 515 0.555 175.5 73.0 73.0

*Series

compensated line

(Degree of comp-

40%)

A. POWERGRID

NLDC 2012 REACTIVE POWER MANAGEMENT-a resource handbook 2 OF 26

ANNEXURE 3


NORTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt.

Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used

as Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

Remarks

27 400 Balia Mau 1 D/C 9 Twin Moose 0.00 0.00 515 0.555 5.1 5.1 5.1

28 400 Balia Mau 2 D/C 9 Twin Moose 0.00 0.00 515 0.555 5.1 5.1 5.1

29 400 Ballabgarh G.Noida 1 D/C 43 Quad Bersimis 0.00 0.00 691 0.746 31.9 31.9 31.9

30 400 Ballabgarh Gurgaon 1 S/C 43 Twin Moose 0.00 0.00 515 0.555 23.7 23.7 23.7

31 400 Ballabgarh Maharanibagh 1 D/C 61 Quad Bersimis 0.00 0.00 691 0.746 45.3 45.3 45.3

32 400 Bareilly PG Moradabad 1 S/C 93 Twin Moose 0.00 0.00 515 0.555 51.4 51.4 51.4

33 400 Bareilly PG Moradabad 2 S/C 92 Twin Moose 0.00 0.00 515 0.555 50.9 50.9 50.9

34 400 Bareilly UP Bareilly PG 1 D/C 14 Twin Moose 45.35 -1 45.35 -1 515 0.555 7.9 -82.8 -82.8

35 400 Bareilly UP Bareilly PG 2 D/C 14 Twin Moose 45.35 -1 45.35 -1 515 0.555 7.9 -82.8 -82.8

36 400 Bassi Bhiwadi 1 S/C 235 Twin Moose 45.35 1 0.00 515 0.555 130.4 85.1 130.4

37 400 Bassi Bhiwadi 2 S/C 220 Twin Moose 45.35 1 0.00 515 0.555 122.3 76.9 122.3

38 400 Bassi Heerapura 1 S/C 48 Twin Moose 0.00 0.00 515 0.555 26.5 26.5 26.5

39 400 Bassi Heerapura 2 S/C 49 Twin Moose 0.00 0.00 515 0.555 27.2 27.2 27.2

40 400 Bawana (CCGT) Bahadurgarh 1 D/C 49 Twin Moose 0.00 0.00 515 0.555 27.2 27.2 27.2

41 400 Bawana (CCGT) Hisar 1 S/C 132 Twin Moose 0.00 0.00 515 0.555 73.1 73.1 73.1

42 400 Bhinmal Kankroli 1 D/C 202 Twin Moose 45.35 -1 45.35 1 515 0.555 112.0 21.3 66.6

43 400 Bhiwadi Gurgaon 1 S/C 83 Twin Moose 0.00 0.00 515 0.555 46.0 46.0 46.0

44 400 Bhiwadi Hissar 1 S/C 212 Twin Moose 0.00 45.35 1 515 0.555 117.4 72.1 117.4

45 400 Bhiwadi Moga 1 D/C 350 Twin Moose 0.00 57.14 -1 515 0.555 194.3 137.1 137.1

46 400 Bhiwadi Moga 2 D/C 350 Twin Moose 0.00 57.14 -1 515 0.555 194.3 137.1 137.1

47 400 Chamera-II Chamera-I 1 S/C 36 Twin Moose 0.00 0.00 515 0.555 20.1 20.1 20.1

48 400 Chamera-II Kishenpur 1 S/C 135 Twin Moose 0.00 0.00 515 0.555 74.8 74.8 74.8

49 400 Chamera-II Chamba 1 S/C 0.375 Twin Moose 0.00 0.00 515 0.555 0.2 0.2 0.2

50 400 Chamera-I Jalandhar 1 D/C 152 Twin ACAR 45.35 -1 0.00 557 0.555 84.4 39.1 39.1

51 400 Chamera-I Jalandhar 2 D/C 152 Twin ACAR 45.35 -1 0.00 557 0.555 84.4 39.1 39.1

52 400 Dadri NCTPP G.Noida 1 D/C 13 Quad Bersimis 0.00 0.00 691 0.746 9.9 9.9 9.9

53 400 Dadri NCTPP Maharanibagh 1 D/C 54 Quad Bersimis 0.00 0.00 691 0.746 40.6 40.6 40.6

54 400 Dadri NCTPP Malerkotla 1 S/C 297 Twin Moose 0.00 57.14 -1 515 0.555 164.9 107.8 107.8

55 400 Dadri NCTPP Mandola 1 D/C 46 Quad Bersimis 0.00 0.00 691 0.746 34.5 34.5 34.5

56 400 Dadri NCTPP Mandola 2 D/C 46 Quad Bersimis 0.00 0.00 691 0.746 34.5 34.5 34.5


ANNEXURE 3


NORTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt.

Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used

as Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

Remarks

57 400 Dadri NCTPP Muradnagar 1 S/C 33 Twin Moose 0.00 0.00 515 0.555 18.4 18.4 18.4

58 400 Dadri NCTPP Panipat 1 S/C 112 Twin Moose 0.00 0.00 515 0.555 62.3 62.3 62.3

59 400 Dadri NCTPP Panipat 2 S/C 117 Twin Moose 0.00 0.00 515 0.555 64.8 64.8 64.8

60 400 Dulhasti Kishenpur 1 S/C 120 Twin Moose 0.00 0.00 515 0.555 66.5 66.5 66.5

61 400 Fatehabad Hissar 1 D/C 89 Twin Moose 0.00 0.00 515 0.555 49.2 49.2 49.2

62 400 Gorakhpur PG Gorakhpur UP 1 D/C 46 Twin Moose 0.00 0.00 515 0.555 25.5 25.5 25.5

63 400 Gorakhpur PG Gorakhpur UP 2 D/C 46 Twin Moose 0.00 0.00 515 0.555 25.5 25.5 25.5

64 400 Gorakhpur PG Lucknow PG 3 D/C 262 Twin Moose 57.14 1 57.14 1 515 0.555 145.4 31.1 145.4

65 400 Gorakhpur PG Lucknow PG 4 D/C 262 Twin Moose 57.14 1 57.14 1 515 0.555 145.4 31.1 145.4

66 400 Kaithal Hissar 1 S/C 113 Triple Snowbird 0.00 45.35 1 605 0.656 74.1 28.8 74.1

67 400 Kaithal Hissar 2 S/C 113 Triple Snowbird 0.00 0.00 605 0.656 74.2 74.2 74.2

68 400 Kankroli Jodhpur 1 S/C 187 Twin Moose 45.35 -1 0.00 515 0.555 103.8 58.4 58.4

69 400 Kanpur Agra 1 S/C 240 Twin Moose 45.35 -1 45.35 -1 515 0.555 133.2 42.5 42.5

70 400 Kanpur Auraiya 1 D/C 73 Twin Moose 0.00 0.00 515 0.555 40.3 40.3 40.3

71 400 Kanpur Auraiya 2 D/C 73 Twin Moose 0.00 0.00 515 0.555 40.6 40.6 40.6

72 400 Kanpur Ballabgarh 1 S/C 386 Twin Moose 72.56 -1 72.56 -1 515 0.555 214.1 68.9 68.9

73 400 Kanpur Ballabgarh 2 D/C 372 Twin Moose 72.56 -1 515 0.555 206.2 133.6 133.6

74 400 Kanpur Ballabgarh 3 D/C 372 Twin Moose 72.56 -1 72.56 -1 515 0.555 206.2 61.1 61.1

75 400 Kanpur Fatehpur 2 S/C 100 Twin Moose 0.00 0.00 515 0.555 55.5 55.5 55.5

76 400 Kanpur Panki 1 S/C 6 Twin Moose 0.00 0.00 515 0.555 3.1 3.1 3.1

77 400 Kanpur Panki 2 S/C 6 Twin Moose 0.00 0.00 515 0.555 3.2 3.2 3.2

78 400 Kishenpur Wagoora 1 D/C 183 Twin Moose 0.00 45.35 1 515 0.555 101.3 56.0 101.3

79 400 Kishenpur Wagoora 2 D/C 183 Twin Moose 0.00 45.35 1 515 0.555 101.3 56.0 101.3

80 400 Kota Merta 1 D/C 256 Twin Moose 45.35 -1 45.35 -1 515 0.555 141.9 51.2 51.2

81 400 Lucknow PG Bareilly PG 1 D/C 256 Twin Moose 45.35 -1 45.35 -1 515 0.555 141.8 51.1 51.1

82 400 Lucknow PG Bareilly PG 2 D/C 256 Twin Moose 45.35 -1 45.35 -1 515 0.555 141.8 51.1 51.1

83 400 Lucknow PG Lucknow UP 1 S/C 63 Twin Moose 0.00 0.00 515 0.555 35.0 35.0 35.0

84 400 Lucknow PG Unnao 1 D/C 74 Twin Moose 0.00 0.00 515 0.555 41.0 41.0 41.0

85 400 Lucknow PG Unnao 2 D/C 74 Twin Moose 0.00 0.00 515 0.555 41.0 41.0 41.0

*Series

Compensated

lines,Ckt 1- 35%,

Ckt-2 & 3-40%


ANNEXURE 3


NORTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt.

Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used

as Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

Remarks

86 400 Lucknow UP Bareilly PG 1 S/C 279 Twin Moose 0.00 0.00 515 0.555 154.7 154.7 154.7

87 400 Ludhiana Jalandhar 1 S/C 85 Twin Moose 0.00 0.00 515 0.555 47.1 47.1 47.1

88 400 Ludhiana Malerkotla 1 S/C 36 Twin Moose 0.00 0.00 515 0.555 19.8 19.8 19.8

89 400 Ludhiana Patiala 1 D/C 78 Twin Moose 0.00 0.00 515 0.555 43.3 43.3 43.3

90 400 Ludhiana Patiala 2 D/C 78 Twin Moose 0.00 0.00 515 0.555 43.3 43.3 43.3

91 400 Mainpuri Ballabgarh 1 D/C 236 Twin Moose 0.00 0.00 515 0.555 130.9 130.9 130.9

92 400 Mainpuri Ballabgarh 2 D/C 236 Twin Moose 0.00 0.00 515 0.555 130.9 130.9 130.9

93 400 Malerkotla Patiala 1 S/C 63 Twin Moose 0.00 0.00 515 0.555 34.7 34.7 34.7

94 400 Meerut Kaithal 1 D/C 164 Quad Moose 0.00 45.35 -1 687 0.740 121.0 75.6 75.6

95 400 Meerut Kaithal 2 D/C 164 Quad Moose 0.00 45.35 -1 687 0.740 121.0 75.6 75.6

96 400 Meerut Mandola 1 D/C 60 Twin Moose 0.00 0.00 515 0.555 33.2 33.2 33.2

97 400 Meerut Mandola 2 D/C 60 Twin Moose 0.00 0.00 515 0.555 33.2 33.2 33.2

98 400 Meerut Muzzafarnagar 1 S/C 37 Twin Moose 0.00 0.00 515 0.555 20.8 20.8 20.8

99 400 Moga Fatehabad 1 D/C 179 Twin Moose 0.00 57.14 1 515 0.555 99.5 42.4 99.5

100 400 Moga Hissar 1 D/C 209 Twin Moose 0.00 45.35 1 515 0.555 116.2 70.9 116.2

101 400 Moga Jalandhar 1 D/C 85 Twin Moose 0.00 0.00 515 0.555 47.3 47.3 47.3

102 400 Moga Jalandhar 2 D/C 85 Twin Moose 0.00 0.00 515 0.555 47.3 47.3 47.3

103 400 Moradabad Muradnagar 1 S/C 133 Twin Moose 0.00 0.00 515 0.555 73.8 73.8 73.8

104 400 Nalagarh Patiala 1 D/C 94 Triple Snowbird 0.00 0.00 605 0.656 61.5 61.5 61.5

105 400 Nalagarh Patiala 2 D/C 94 Triple Snowbird 0.00 0.00 605 0.656 61.7 61.7 61.7

106 400 Nathpa Jhakri Abdullapur 1 D/C 180 Triple Snowbird 0.00 45.35 1 605 0.656 118.0 72.7 118.0

107 400 Nathpa Jhakri Abdullapur 2 D/C 180 Triple Snowbird 0.00 45.35 1 605 0.656 118.0 72.7 118.0

108 400 Nathpa Jhakri Nalagarh 1 D/C 144 Triple Snowbird 0.00 45.35 1 605 0.656 94.5 49.1 94.5

109 400 Nathpa Jhakri Nalagarh 2 D/C 144 Triple Snowbird 0.00 45.35 1 605 0.656 94.5 49.1 94.5

110 400 Patiala Kaithal 1 D/C 126 Triple Snowbird 0.00 0.00 605 0.656 82.7 82.7 82.7

111 400 Patiala Kaithal 2 D/C 126 Triple Snowbird 0.00 0.00 605 0.656 82.7 82.7 82.7

112 400 RAPS-C Kankroli 1 D/C 199 Twin Moose 0.00 45.35 1 515 0.555 110.2 64.8 110.2

113 400 RAPS-C Kankroli 2 D/C 199 Twin Moose 0.00 45.35 1 515 0.555 110.2 64.8 110.2

114 400 RAPS-C Kota 1 S/C 51 Twin Moose 0.00 0.00 515 0.555 28.0 28.0 28.0

115 400 Rihand Allahabad 1 D/C 279 Twin Moose 0.00 45.35 1 515 0.555 155.0 109.7 155.0

116 400 Rihand Allahabad 2 D/C 279 Twin Moose 0.00 45.35 1 515 0.555 155.0 109.7 155.0


ANNEXURE 3


NORTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt.

Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used

as Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

Remarks

117 400 Sarnath Allahabad 1 D/C 144 Twin Moose 0.00 0.00 515 0.555 79.9 79.9 79.9

118 400 Singrauli Allahabad 1 S/C 224 Twin Moose 72.56 -1 0.00 515 0.555 124.3 51.8 51.8

119 400 Singrauli Allahabad 2 S/C 202 Twin Moose 72.56 -1 0.00 515 0.555 112.1 39.5 39.5

120 400 Singrauli Anpara 1 S/C 25 Twin Moose 0.00 0.00 515 0.555 13.9 13.9 13.9

121 400 Singrauli Anpara 1 S/C 398 Twin Moose 0.00 0.00 515 0.555 220.9 220.9 220.9

122 400 Singrauli Lucknow UP 1 S/C 409 Twin Moose 57.14 -1 57.14 -1 515 0.555 226.8 112.5 112.5

123 400 Singrauli Rihand 1 S/C 42 Twin Moose 0.00 0.00 515 0.555 23.3 23.3 23.3

124 400 Singrauli Rihand 2 S/C 44 Twin Moose 0.00 0.00 515 0.555 24.4 24.4 24.4

125 400 Singrauli Vindhyachal 1 S/C 3 Twin Moose 0.00 0.00 515 0.555 1.8 1.8 1.8

126 400 Singrauli Vindhyachal 2 S/C 5 Twin Moose 0.00 0.00 515 0.555 2.7 2.7 2.7

127 400 Shree Cement Kota 1 D/C 207 Twin Moose 0.00 45.35 -1 515 0.555 114.9 69.5 69.5

128 400 Shree Cement Merta 2 D/C 103 Twin Moose 0.00 45.35 -1 515 0.555 57.2 11.8 11.8

129 400 Tehri pooling Koteswar 1 D/C 3 Twin Moose 0.00 0.00 515 0.555 1.4 1.4 1.4

130 400 Tehri pooling Koteswar 2 D/C 3 Twin Moose 0.00 0.00 515 0.555 1.4 1.4 1.4

131 400 Uri-I Wagoora 1 D/C 95 Twin Moose 45.35 -1 0.00 515 0.555 52.7 7.4 7.4

132 400 Uri-I Wagoora 2 D/C 95 Twin Moose 45.35 -1 0.00 515 0.555 52.7 7.4 7.4

133 400 Kishenpur Moga 1 S/C 275 Quad Bersimis 57.14 1 57.14 1 633 0.730 201.0 86.8 201.0765kV Line Charged

at 400kV

134 400 Kishenpur Moga 2 S/C 287 Quad Bersimis 57.14 1 57.14 1 633 0.730 209.6 95.3 209.6765kV Line Charged

at 400kV

135 400 Koteshwar Pooling Meerut 1 S/C 161 Quad Bersimis 0.00 45.35 -1 633 0.730 117.5 72.2 72.2 765kV Line Charged

at 400kV

136 400 Koteshwar Pooling Meerut 2 S/C 161 Quad Bersimis 0.00 45.35 -1 633 0.730 117.2 71.8 71.8765kV Line Charged

at 400kV

137 400Koteshwar

PoolingTehri 1 S/C 25 Quad Bersimis 0.00 0.00 633 0.730 18.3 18.3 18.3

765kV Line Charged

at 400kV

138 400Koteshwar

PoolingTehri 2 S/C 25 Quad Bersimis 0.00 0.00 633 0.730 18.3 18.3 18.3

765kV Line Charged

at 400kV

139 400Koteshwar

PoolingKoteshwar HEP 1 S/C 3 Quad Bersimis 0.00 0.00 633 0.746 2.2 2.2 2.2

140 400Koteshwar

PoolingKoteshwar HEP 2 S/C 3 Quad Bersimis 0.00 0.00 633 0.746 2.2 2.2 2.2

141 400 Dhauliganga Bareilly(UP) 1 D/C 235 Twin Moose 22.68 -1 515 0.555 130.2 107.5 107.5

142 400 Dhauliganga Pithoragarh 1 D/C 59 Twin Moose 0.00 0.00 515 0.555 32.7 32.7 32.7

143 400 Pithoragarh Bareilly(UP) 1 D/C 178 Twin Moose 0.00 0.00 515 0.555 98.7 98.7 98.7

LILO portion is of

Shree Cement


ANNEXURE 3


NORTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt.

Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used

as Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

Remarks

0.0 0.0

144 400 Bareilly PG Mandola 1 D/C 241 Twin Moose 45.35 -1 45.35 -1 515 0.555 133.7 43.0 43.0

145 400 Bareilly PG Mandola 2 D/C 241 Twin Moose 45.35 -1 45.35 -1 515 0.555 133.7 43.0 43.0

146 400 Gorakhpur PG Lucknow PG 1 D/C 246 Twin Moose 0.00 0.00 515 0.555 136.5 136.5 136.5

147 400 Gorakhpur PG Lucknow PG 2 D/C 246 Twin Moose 0.00 0.00 515 0.555 136.5 136.5 136.5

148 400 Dehar Bhiwani 1 S/C 312 Twin Morkulla 0.00 45.35 -1 515 0.555 173.2 127.8 127.8

149 400 Dehar Panipat 1 S/C 262 Twin Morkulla 0.00 65.00 -1 515 0.555 145.4 80.4 80.4

150 400 Bawana Mundka 1 D/C 22 Quad bersimis 0.00 0.00 691 0.746 16.4 16.4 16.4

151 400 Bawana Mundka 2 D/C 20 Quad bersimis 0.00 0.00 691 0.746 14.9 14.9 14.9

152 400 Ballabgarh Bamnoli 1 D/C 53 Quad bersimis 0.00 0.00 691 0.746 39.4 39.4 39.4

153 400 Ballabgarh Bamnoli 2 D/C 53 Quad bersimis 0.00 0.00 691 0.746 39.4 39.4 39.4

154 400 Bamnoli Mundka 1 D/C 17 Quad bersimis 0.00 0.00 691 0.746 12.7 12.7 12.7

155 400 Bamnoli Mundka 2 D/C 17 Quad bersimis 0.00 0.00 691 0.746 12.7 12.7 12.7

156 400 Mandola Bawana 1 D/C 24 Quad bersimis 0.00 0.00 691 0.746 17.8 17.8 17.8

157 400 Mandola Bawana 2 D/C 24 Quad bersimis 0.00 0.00 691 0.746 17.8 17.8 17.8

E. HVPNL

158 400 Jhajjar Daulatabad 1 D/C 64 Twin Moose 0.00 0.00 515 0.555 35.5 35.5 35.5

159 400 Jhajjar Jhajjar New 1 D/C 30 Twin Moose 0.00 0.00 515 0.555 16.7 16.7 16.7

160 400 Jhajjar Daulatabad 1 D/C 34 Twin Moose 0.00 0.00 515 0.555 18.9 18.9 18.9

161 400 Khedar Fathehabad 1 D/C 40 Twin Moose 0.00 0.00 515 0.555 22.2 22.2 22.2

162 400 Khedar Fathehabad 2 D/C 40 Twin Moose 0.00 0.00 515 0.555 22.0 22.0 22.0

163 400 Khedar Kirori 1 D/C 6 Twin Moose 0.00 0.00 515 0.555 3.4 3.4 3.4

164 400 Khedar Kirori 2 D/C 7 Twin Moose 0.00 0.00 515 0.555 3.6 3.6 3.6

B. POWERLINK

*Series

compensated line

(30%)

C. BBMB

D. DTL


ANNEXURE 3


NORTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt.

Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used

as Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

Remarks

165 400 Jhajjar (IGSTPS) Mundka 1 D/C 66 Twin Moose 0.00 0.00 515 0.555 36.6 36.6 36.6

166 400 Jhajjar (IGSTPS) Mundka 2 D/C 66 Twin Moose 0.00 0.00 515 0.555 36.6 36.6 36.6

167 400 Baglihar Kishenpur 1 D/C 68 Twin Moose 0.00 0.00 515 0.555 37.7 37.7 37.7

168 400 Baglihar Kishenpur 2 D/C 68 Twin Moose 0.00 0.00 515 0.555 37.7 37.7 37.7

169 400 Barmer Rajwest 1 D/C 20 Twin Moose 0.00 0.00 515 0.555 11.1 11.1 11.1

170 400 Barmer Rajwest 2 D/C 20 Twin Moose 0.00 0.00 515 0.555 11.1 11.1 11.1

171 400 Bhilwara Chhabra 1 S/C 285 Twin Moose 45.35 -1 45.35 -1 515 0.555 158.2 67.5 67.5

172 400 Heerapura Hindaun 1 S/C 192 Twin Moose 45.35 -1 0.00 515 0.555 106.6 61.2 61.2

173 400 Hindaun Chhabra 1 S/C 305 Twin Moose 45.35 -1 45.35 -1 515 0.555 169.3 78.6 78.6

174 400 Merta Heerapura 1 S/C 180 Twin Moose 0.00 0.00 515 0.555 99.9 99.9 99.9

175 400 Merta Jodhpur 1 S/C 120 Twin Moose 0.00 0.00 515 0.555 66.6 66.6 66.6

176 400 Merta Ratangarh 1 S/C 180 Twin Moose 0.00 0.00 515 0.555 99.9 99.9 99.9

177 400 Rajwest Jodhpur 1 D/C 220 Twin Moose 0.00 0.00 515 0.555 122.1 122.1 122.1

178 400 Rajwest Jodhpur 2 D/C 220 Twin Moose 0.00 0.00 515 0.555 122.1 122.1 122.1

179 400 Suratgarh Bikaner 1 S/C 162 Twin Moose 0.00 0.00 515 0.555 89.9 89.9 89.9

180 400 Suratgarh Ratangarh 1 S/C 144 Twin Moose 0.00 0.00 515 0.555 79.9 79.9 79.9

181 400 Suratgarh Ratangarh 2 S/C 144 Twin Moose 0.00 0.00 515 0.555 79.9 79.9 79.9

182 400 Akal Barmer 1 S/C 130 Twin Moose 0.00 0.00 515 0.555 72.2 72.2 72.2

183 400 Dholpur Hindaun 1 S/C 100 Twin Moose 0.00 0.00 515 0.555 55.5 55.5 55.5 Charged at 220kV

184 400 Kota(PG) KTPS 1 S/C 5 Twin Moose 0.00 0.00 515 0.555 2.8 2.8 2.8 Charged at 220kV

185 400 Kota(PG) KTPS 1 S/C 5 Twin Moose 0.00 0.00 515 0.555 2.8 2.8 2.8 Charged at 220kV

I. PTCUL 0.0 0.0

186 400 Muradabad Kashipur 1 S/C 108 Twin Moose 0.00 0.00 515 0.555 59.8 59.8 59.8

187 400 Rishikesh Kashipur 1 S/C 172 Twin Moose 0.00 0.00 515 0.555 95.5 95.5 95.5

188 400 Roorkee Rishikesh 1 S/C 50 Twin Moose 0.00 0.00 515 0.555 27.7 27.7 27.7

F. APCPL (Aravali Power corporation pvt ltd.)

G. PDD (Jammu & Kashmir)

H. RRVPNL


ANNEXURE 3


NORTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt.

Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used

as Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

Remarks

0.0 0.0

189 400 Agra UP Muradnagar 1 S/C 194 Twin Moose 0.00 0.00 515 0.555 107.7 107.7 107.7

190 400 Agra UP Unnao 1 S/C 279 Twin Moose 45.35 -1 45.35 -1 515 0.555 154.9 64.2 64.2

191 400 Anpara Mau 1 S/C 262 Twin Moose 57.14 -1 0.00 515 0.555 145.6 88.4 88.4

192 400 Anpara Obra 1 S/C 40 Twin Moose 0.00 0.00 515 0.555 22.2 22.2 22.2

193 400 Anpara Sarnath 1 D/C 158 Twin Moose 0.00 0.00 515 0.555 87.5 87.5 87.5

194 400 Anpara Sarnath 2 D/C 158 Twin Moose 0.00 0.00 515 0.555 87.5 87.5 87.5

195 400 Azamgarh Mau 1 S/C 48 Twin Moose 0.00 0.00 515 0.555 26.8 26.8 26.8

196 400 Azamgarh Sultanpur 1 S/C 126 Twin Moose 0.00 0.00 515 0.555 69.7 69.7 69.7

197 400 Bareilly UP Unnao 1 D/C 271 Twin Moose 45.35 -1 45.35 -1 515 0.555 150.4 59.7 59.7

198 400 Bareilly UP Unnao 2 D/C 271 Twin Moose 45.35 -1 45.35 -1 515 0.555 150.4 59.7 59.7

199 400 Gorakhpur UP Azamgarh 1 S/C 90 Twin Moose 0.00 0.00 515 0.555 50.0 50.0 50.0

200 400 Muzzafarnagar Muradnagar 1 S/C 72 Twin Moose 0.00 0.00 515 0.555 40.0 40.0 40.0

201 400 Muzzafarnagar Vishnuprayag 1 D/C 280 Twin Moose 45.35 -1 45.35 -1 515 0.555 155.4 64.7 64.7

202 400 Muzzafarnagar Vishnuprayag 2 D/C 280 Twin Moose 45.35 -1 45.35 -1 515 0.555 155.4 64.7 64.7

203 400 Obra Sultanpur 1 S/C 230 Twin Moose 45.35 -1 45.35 -1 515 0.555 127.9 37.2 37.2

204 400 Panki Muradnagar 1 S/C 397 Twin Moose 45.35 -1 45.35 -1 515 0.555 220.3 129.6 129.6*Series

Compensated line

(40%)205 400 Panki Obra 1 S/C 388 Twin Moose 45.35 -1 45.35 -1 515 0.555 215.1 124.4 124.4

206 400 Roorkee Muzzafarnagar 1 S/C 71 Twin Moose 0.00 0.00 515 0.555 39.4 39.4 39.4

207 400 Sarnath Azamgarh 1 S/C 97 Twin Moose 0.00 45.35 -1 515 0.555 53.7 8.3 8.3

208 400 Sultanpur Lucknow PG 1 S/C 209 Twin Moose 0.00 0.00 515 0.555 116.1 116.1 116.1

209 400 Unnao Lucknow UP 1 S/C 39 Twin Moose 0.00 0.00 515 0.555 21.8 21.8 21.8

210 400 Unnao Panki 1 S/C 49 Twin Moose 0.00 0.00 515 0.555 27.1 27.1 27.1

211 765 Anpara Unnao 1 S/C 409 Quad Bersimis 330.00 -1 330.00 -1 633 0.730 298.6 -361.4 -361.4

212 400 BaspaKarcham

Wangtoo1 D/C 18 Triple snowbird 0.00 0.00 605 0.656 11.8 11.8 11.8

213 400 BaspaKarcham

Wangtoo2 D/C 18 Triple snowbird 0.00 0.00 605 0.656 11.8 11.8 11.8

214 400Karcham

WangtooNJPC 1 D/C 17 Triple snowbird 0.00 0.00 605 0.656 11.2 11.2 11.2

215 400Karcham

WangtooNJPC 2 D/C 17 Triple snowbird 0.00 0.00 605 0.656 11.2 11.2 11.2

29335 2642.0 3460.8 16886.1 10783.3 12168.3

LILO portion is of

JKHCL (Jaypee

Karcham Hydro

Corporation Ltd)

TOTAL

J. UPPTCL

K. JHPL (Jaypee Hydro Power Limited)

*Series

Compensated line

(45%)


ANNEXURE 3


WESTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor (Yes=1,

No=-1)

SIL

Line

charging

Mvar/km

Total

Line

Charging

Mvar of

the line

MVAR

relief

available

when line is

opened

MVAR relief

available when

line is opened

& Line Reactor

is used as Bus

Reactor

*

Remarks

CENTRAL SECTOR

1 765 SIPAT SEONI S/C 1 S/C 351 Quad Bersimis 0.00 240.00 2250 2.910 1021.4 781.41 1021.41

2 765 SIPAT SEONI S/C 1 S/C 351 Quad Bersimis 0.00 240.00 2250 2.910 1021.4 781.41 1021.41

3 765 BINA GWALIOR 1 S/C 235 Quad Bersimis 45.35 0.00 633 0.730 171.6 126.20 171.55 765kV Line Charged

at 400kV

4 765 BINA GWALIOR 1 S/C 235 Quad Bersimis 0.00 0.00 633 0.730 171.6 171.55 171.55 765kV Line Charged

at 400kV

5 765 SEONI BINA 1 S/C 293 Quad Bersimis 0.00 0.00 633 0.730 213.9 213.89 213.89 765kV Line Charged

at 400kV

6 765 Seoni Wardha 1 S/C 274 Quad Bersimis 0.00 0.00 633 0.730 200.0 200.02 200.02 765kV Line Charged

at 400kV

7 400 Korba(NTPC) Korba (W) 1 S/C 14 Twin Moose 0.00 0.00 515 0.555 7.8 7.77 7.77

8 400 Wardha Parli (PG) Quad 1 D/C 341 Quad Moose 0.00 0.00 687 0.74 252.3 252.34 252.34

9 400 Wardha Parli (PG) Quad 2 D/C 341 Quad Moose 0.00 0.00 687 0.74 252.3 252.34 252.34

10 400 Korba (NTPC) ACBIL 1 S/C 21 Twin Moose 0.00 0.00 515 0.555 11.7 11.66 11.66

11 400 ACBIL Bhatapara 1 S/C 107 Twin Moose 0.00 0.00 515 0.555 59.4 59.39 59.39

12 400 Mundra (TATA) Bachchau 1 D/C 282 Triple Snowbird 0.00 0.00 605 0.656 185.0 184.99 184.99

13 400 Mundra (TATA) Bachchau 2 D/C 282 Triple Snowbird 0.00 0.00 605 0.656 185.0 184.99 184.99

14 400 Bachchau Ranchorpura

(Vadavi)1 D/C 99 Triple Snowbird 0.00 45.35 -1 605 0.656 64.9 19.59 19.59

15 400 Bachchau Ranchorpura

(Vadavi)2 D/C 99 Triple Snowbird 0.00 45.35 -1 605 0.656 64.9 19.59 19.59

16 400 Korba (NTPC) Raipur 1 D/C 212 Twin Moose 0.00 45.35 515 0.555 117.7 72.31 117.66

17 400 Korba (NTPC) Raipur 2 D/C 212 Twin Moose 0.00 0.00 515 0.555 117.7 117.66 117.66

18 400 Bhadrawati Parli (PG) D/C 1 D/C 388 Twin Moose 0.00 0.00 515 0.555 215.3 215.34 215.34

19 400 Bhadrawati Parli (PG) D/C 2 D/C 388 Twin Moose 0.00 0.00 515 0.555 215.3 215.34 215.34

20 400 Raigarh Rourkela - I 1 S/C 212 Twin Moose 0.00 0.00 515 0.555 117.7 117.66 117.66

21 400 Raigarh Sterlite-II 1 S/C 127 Twin Moose 0.00 0.00 515 0.555 70.5 70.49 70.49

22 400 Raigarh Rourkela - III & IV 1 D/C 220 Twin Moose 0.00 0.00 515 0.555 122.1 122.10 122.10

23 400 Raigarh Rourkela - III & IV 2 D/C 220 Twin Moose 0.00 0.00 515 0.555 122.1 122.10 122.10

24 400 Dehgam Pirana I & II (PG) 1 D/C 46 Twin Moose 0.00 0.00 515 0.555 25.5 25.53 25.53

25 400 Dehgam Pirana I & II (PG) 2 D/C 46 Twin Moose 0.00 0.00 515 0.555 25.5 25.53 25.53

26 400 Birsinghpur Damoh D/C 1 D/C 227 Twin Moose 0.00 0.00 515 0.555 126.0 125.99 125.99

NLDC, 2012 REACTIVE POWER MANAGEMENT-a resource handbook 10 OF 26

ANNEXURE 3


WESTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor (Yes=1,

No=-1)

SIL

Line

charging

Mvar/km

Total

Line

Charging

Mvar of

the line

MVAR

relief

available

when line is

opened

MVAR relief

available when

line is opened

& Line Reactor

is used as Bus

Reactor

*

Remarks

27 400 Birsinghpur Damoh D/C 2 D/C 227 Twin Moose 0.00 0.00 515 0.555 126.0 125.99 125.99

28 400 Parli (MSETCL) Parli (Powergrid) 1 D/C 7 Twin Moose 0.00 0.00 515 0.555 3.9 3.89 3.89

29 400 Parli (MSETCL) Parli (Powergrid) 2 D/C 7 Twin Moose 0.00 0.00 515 0.555 3.9 3.89 3.89

30 400 Bina Sujalpur D/C 1 D/C 198 Twin Moose 57.14 45.35 515 0.555 109.9 7.40 109.89

31 400 Bina Sujalpur D/C 2 D/C 198 Twin Moose 57.14 45.35 515 0.555 109.9 7.40 109.89

32 400 Sujalpur Nagda D/C 1 D/C 150 Twin Moose 0.00 57.14 515 0.555 83.3 26.11 83.25

33 400 Sujalpur Nagda D/C 2 D/C 150 Twin Moose 0.00 57.14 515 0.555 83.3 26.11 83.25

34 400 Korba(NTPC) Bhilai I 1 S/C 197 Twin Moose 0.00 45.35 515 0.555 109.3 63.98 109.34

35 400 Korba(NTPC) Bhilai II 1 S/C 192 Twin Moose 0.00 45.35 515 0.555 106.6 61.21 106.56

36 400 Korba(NTPC) Pathadi s/c 1 S/C 32 Twin Moose 0.00 0.00 515 0.555 17.8 17.76 17.76

37 400 Pathadi Raipur s/c 1 S/C 189 Twin Moose 0.00 0.00 515 0.555 104.9 104.90 104.90

38 400 Bhatapara Bhilai 1 S/C 93 Twin Moose 0.00 0.00 515 0.555 51.6 51.62 51.62

39 400 Vindhyachal Korba(NTPC) -I 1 S/C 215 Twin Moose 45.35 0.00 515 0.555 119.3 73.97 119.33

40 400 Vindhyachal- Korba(NTPC) -II 1 S/C 289 Twin Moose 0.00 0.00 515 0.555 160.4 160.40 160.40

41 400 Bhilai Koradi 1 S/C 272 Twin Moose 45.35 45.35 515 0.555 151.0 60.26 150.96

42 400 Bhilai Bhadravati 1 S/C 322 Twin Moose 72.56 45.35 515 0.555 178.7 60.80 178.71

43 400 Raipur Bhadravati I 1 S/C 333 Twin Moose 72.56 45.35 515 0.555 184.8 66.90 184.82

44 400 Raipur Bhadravati 1 D/C 345 Twin Moose 0.00 0.00 515 0.555 191.5 191.48 191.48

45 400 Raipur Bhadravati 2 D/C 345 Twin Moose 0.00 0.00 515 0.555 191.5 191.48 191.48

46 400 Koradi Satpura 1 S/C 149 Twin Moose 0.00 45.35 515 0.555 82.7 37.34 82.70

47 400 Satpura Itarsi 1 S/C 79 Twin Moose 0.00 0.00 515 0.555 43.8 43.85 43.85

48 400 Itarsi Indore I 1 S/C 214 Twin Moose 45.35 45.35 515 0.555 118.8 28.07 118.77

49 400 Itarsi Indore II 1 S/C 215 Twin Moose 45.35 45.35 515 0.555 119.3 28.62 119.33

50 400 Itarsi Khandwa I 1 S/C 197 Twin Moose 0.00 0.00 515 0.555 109.3 109.34 109.34

51 400 Itarsi Khandwa II 1 S/C 197 Twin Moose 0.00 0.00 515 0.555 109.3 109.34 109.34

52 400 Khandwa Dhule I 1 S/C 262 Twin Moose 45.35 45.35 515 0.555 145.4 54.71 145.41

53 400 Khandwa Dhule II 1 S/C 262 Twin Moose 45.35 45.35 515 0.555 145.4 54.71 145.41

54 400 Indore Asoj I 1 S/C 288 Twin Moose 45.35 -1 45.35 -1 515 0.555 159.8 69.14 69.14

55 400 Indore Asoj II 1 S/C 273 Twin Moose 45.35 -1 45.35 -1 515 0.555 151.5 60.81 60.81

56 400 Bhadravati Chandrapur I 1 D/C 20 Twin Moose 0.00 0.00 515 0.555 11.1 11.10 11.10

57 400 Bhadravati Chandrapur II 2 D/C 20 Twin Moose 0.00 0.00 515 0.555 11.1 11.10 11.10

58 400 Bhadravati Chandrapur III 1 D/C 22 Twin Moose 0.00 0.00 515 0.555 12.2 12.21 12.21


ANNEXURE 3


WESTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor (Yes=1,

No=-1)

SIL

Line

charging

Mvar/km

Total

Line

Charging

Mvar of

the line

MVAR

relief

available

when line is

opened

MVAR relief

available when

line is opened

& Line Reactor

is used as Bus

Reactor

*

Remarks

59 400 Bhadravati Chandrapur IV 2 D/C 22 Twin Moose 0.00 0.00 515 0.555 12.2 12.21 12.21

60 400 Vindhyachal Jabalpur I 1 D/C 360 Twin Moose 57.14 57.14 515 0.555 199.8 85.51 199.80

61 400 Vindhyachal Jabalpur II 2 D/C 360 Twin Moose 57.14 57.14 515 0.555 199.8 85.51 199.80

62 400 Vindhyachal Jabalpur III 3 D/C 387 Twin Moose 57.14 57.14 515 0.555 214.8 100.50 214.79

63 400 Vindhyachal Jabalpur IV 4 D/C 387 Twin Moose 57.14 57.14 515 0.555 214.8 100.50 214.79

64 400 Jabalpur Itarsi I 1 D/C 232 Twin Moose 45.35 45.35 515 0.555 128.8 38.06 128.76

65 400 Jabalpur Itarsi II 2 D/C 232 Twin Moose 45.35 45.35 515 0.555 128.8 38.06 128.76

66 400 Jabalpur Itarsi III 1 D/C 234 Twin Moose 45.35 45.35 515 0.555 129.9 39.17 129.87

67 400 Jabalpur Itarsi IV 2 D/C 234 Twin Moose 45.35 45.35 515 0.555 129.9 39.17 129.87

68 400 Jhanor Dehgam 1 D/C 156 Twin Moose 0.00 0.00 515 0.555 86.6 86.58 86.58

69 400 Jhanor Dehgam 2 D/C 156 Twin Moose 0.00 0.00 515 0.555 86.6 86.58 86.58

70 400 Jhanor Sugen 1 S/C 65 Twin Moose 0.00 0.00 515 0.555 36.1 36.08 36.08

71 400 Dehgam Sugen 1 D/C 156 Twin Moose 0.00 0.00 515 0.555 86.6 86.58 86.58

72 400 Dehgam Sugen 2 D/C 156 Twin Moose 0.00 0.00 515 0.555 86.6 86.58 86.58

73 400 Jhanor GPEC 1 S/C 16 Twin Moose 0.00 0.00 515 0.555 8.9 8.88 8.88

74 400 Vindhyachal Satna I 1 D/C 266 Twin Moose 45.35 45.35 515 0.555 147.6 56.93 147.63

75 400 Vindhyachal Satna II 2 D/C 266 Twin Moose 45.35 45.35 515 0.555 147.6 56.93 147.63

76 400 Vindhyachal Satna III 3 D/C 258 Twin Moose 0.00 45.35 515 0.555 143.2 97.84 143.19

77 400 Vindhyachal Satna IV 4 D/C 258 Twin Moose 0.00 45.35 515 0.555 143.2 97.84 143.19

78 400 Satna Bina I 1 D/C 276 Twin Moose 45.35 45.35 515 0.555 153.2 62.48 153.18

79 400 Satna Bina II 2 D/C 276 Twin Moose 45.35 45.35 515 0.555 153.2 62.48 153.18

80 400 Satna Bina III 1 D/C 273 Twin Moose 45.35 45.35 515 0.555 151.5 60.81 151.52

81 400 Satna Bina IV 2 D/C 273 Twin Moose 45.35 45.35 515 0.555 151.5 60.81 151.52

82 400 Bhilai Raipur I 1 S/C 13 Twin Moose 0.00 0.00 515 0.555 7.2 7.22 7.22

83 400 Bhilai Raipur II 1 S/C 17 Twin Moose 0.00 0.00 515 0.555 9.4 9.44 9.44

84 400 Kolhapur Mapusa I 1 D/C 150 Twin Moose 0.00 0.00 515 0.555 83.3 83.25 83.25

85 400 Kolhapur Mapusa II 2 D/C 150 Twin Moose 0.00 0.00 515 0.555 83.3 83.25 83.25

86 400 Raipur Raigarh I 1 D/C 217 Twin Moose 0.00 0.00 515 0.555 120.4 120.44 120.44

87 400 Raipur Raigarh II 2 D/C 217 Twin Moose 0.00 0.00 515 0.555 120.4 120.44 120.44

88 400 Raipur Raigarh III 3 D/C 220 Twin Moose 0.00 0.00 515 0.555 122.1 122.10 122.10

89 400 Raipur Raigarh IV 4 D/C 220 Twin Moose 0.00 0.00 515 0.555 122.1 122.10 122.10

90 400 Tarapur Padge I 1 D/C 91 Twin Moose 0.00 0.00 515 0.555 50.5 50.51 50.51


ANNEXURE 3


WESTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor (Yes=1,

No=-1)

SIL

Line

charging

Mvar/km

Total

Line

Charging

Mvar of

the line

MVAR

relief

available

when line is

opened

MVAR relief

available when

line is opened

& Line Reactor

is used as Bus

Reactor

*

Remarks

91 400 Tarapur Padge II 2 D/C 91 Twin Moose 0.00 0.00 515 0.555 50.5 50.51 50.51

92 400 Tarapur Boisar I 1 D/C 21 Twin Moose 0.00 0.00 515 0.555 11.7 11.66 11.66

93 400 Tarapur Boisar II 2 D/C 21 Twin Moose 0.00 0.00 515 0.555 11.7 11.66 11.66

94 400 Sugen Vapi 1 S/C 118 Twin Moose 0.00 0.00 515 0.555 65.5 65.49 65.49

95 400 Vapi Boisar 1 S/C 91 Twin Moose 0.00 0.00 515 0.555 50.5 50.51 50.51

96 400 Boisar Padge 1 S/C 101 Twin Moose 0.00 0.00 515 0.555 56.1 56.06 56.06

97 400 Bina(PGCIL) Bina(MPPTCL) 1 D/C 1 Twin Moose 0.00 0.00 515 0.555 0.6 0.56 0.56

98 400 Bina(PGCIL) Bina(MPPTCL) 2 D/C 1 Twin Moose 0.00 0.00 515 0.555 0.6 0.56 0.56

99 400 Nagda Dehgam I 1 D/C 332 Twin Moose 45.35 45.35 515 0.555 184.3 93.56 184.26

100 400 Nagda Dehgam II 2 D/C 332 Twin Moose 45.35 45.35 515 0.555 184.3 93.56 184.26

101 400 SeoniKhandwa I

Quad1 D/C 350 AAAC 72.56 72.56 515 0.555 194.3 49.13 194.25

102 400 SeoniKhandwa II

Quad2 D/C 350 AAAC 72.56 72.56 515 0.555 194.3 49.13 194.25

103 400 Khandwa Rajgarh-I 1 D/C 220 Twin Moose 0.00 0.00 515 0.555 122.1 122.10 122.10

104 400 Khandwa Rajgarh- II 2 D/C 220 Twin Moose 0.00 0.00 515 0.555 122.1 122.10 122.10

105 400 Sipat Raipur I 1 D/C 149 Twin Moose 0.00 0.00 515 0.555 82.7 82.70 82.70

106 400 Sipat Raipur II 2 D/C 149 Twin Moose 0.00 0.00 515 0.555 82.7 82.70 82.70

107 400 Wardha Akola-I 1 D/C 165 Twin Moose 0.00 0.00 515 0.555 91.6 91.58 91.58

108 400 Wardha Akola- II 2 D/C 165 Twin Moose 0.00 0.00 515 0.555 91.6 91.58 91.58

109 400 Damoh Bhopal 1 D/C 216 Twin Moose 0.00 0.00 515 0.555 119.9 119.88 119.88

110 400 Damoh Bhopal 2 D/C 216 Twin Moose 0.00 0.00 515 0.555 119.9 119.88 119.88

111 400 MUNDRA SAMI 1 D/C 282 Twin Moose 0.00 45.35 -1 515 0.555 156.5 111.16 111.16

112 400 MUNDRA SAMI 2 D/C 282 Twin Moose 0.00 45.35 -1 515 0.555 156.5 111.16 111.16

113 400 SAMI DEHGAM 1 D/C 152 Twin Moose 0.00 0.00 515 0.555 84.4 84.36 84.36

114 400 SAMI DEHGAM 2 D/C 152 Twin Moose 0.00 0.00 515 0.555 84.4 84.36 84.36

115 400 Sugen Pirana (T) 1 D/C 219 Twin Moose 0.00 40.82 -1 515 0.555 121.5 80.73 80.73

116 400 Sugen Pirana (T) 2 D/C 219 Twin Moose 0.00 40.82 -1 515 0.555 121.5 80.73 80.73

117 400 Raipur NSPCL 1 D/C 13.5 Twin Moose 0.00 0.00 515 0.555 7.5 7.49 7.49

118 400 Raipur NSPCL 2 D/C 13.5 Twin Moose 0.00 0.00 515 0.555 7.5 7.49 7.49

119 400 Hadala Vadinar (ESSAR) 1 D/C 113 Twin Moose 0.00 0.00 515 0.555 62.7 62.72 62.72

120 400 Hadala Vadinar (ESSAR) 2 D/C 113 Twin Moose 0.00 0.00 515 0.555 62.7 62.72 62.72

IPP


ANNEXURE 3


WESTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor (Yes=1,

No=-1)

SIL

Line

charging

Mvar/km

Total

Line

Charging

Mvar of

the line

MVAR

relief

available

when line is

opened

MVAR relief

available when

line is opened

& Line Reactor

is used as Bus

Reactor

*

Remarks

121 400 Pirana (PG) Pirana (T) 1 D/C 5 Twin Moose 0.00 0.00 515 0.555 2.8 2.78 2.78

122 400 Pirana (PG) Pirana (T) 2 D/C 5 Twin Moose 0.00 0.00 515 0.555 2.8 2.78 2.78

MATHYA PRADESH

123 400 Bhopal Bina I & II 1 D/C 135 Twin Moose 0.00 45.35 -1 515 0.555 74.9 29.57 29.57

124 400 Bhopal Bina I & II 2 D/C 135 Twin Moose 0.00 45.35 -1 515 0.555 74.9 29.57 29.57

125 400 Birsingpur Damoh 1 S/C 233 Twin Moose 0.00 45.35 -1 515 0.555 129.3 83.96 83.96

126 400 Damoh Katni 1 S/C 115 Twin Moose 0.00 0.00 515 0.555 63.8 63.83 63.83

127 400 Indirasagar Nagda 1 S/C 105 Twin Moose 0.00 0.00 515 0.555 58.3 58.28 58.28

128 400 Indirasagar Satpura 1 S/C 201 Twin Moose 0.00 0.00 515 0.555 111.6 111.56 111.56

129 400 Itarsi Indore -I 1 S/C 80 Twin Moose 0.00 45.35 -1 515 0.555 44.4 -0.95 -0.95

130 400 Itarsi Indore -II 1 S/C 81 Twin Moose 0.00 45.35 -1 515 0.555 45.0 -0.40 -0.40

131 400 Indore Nagda 1 S/C 105 Twin Moose 0.00 0.00 515 0.555 58.3 58.28 58.28

132 400 Itarsi Bhopal I & II 1 D/C 97 Twin Moose 0.00 0.00 515 0.555 53.8 53.84 53.84

133 400 Itarsi Bhopal I & II 2 D/C 97 Twin Moose 0.00 0.00 515 0.555 53.8 53.84 53.84

134 400 Katni Birsingpur 1 S/C 118 Twin Moose 0.00 0.00 515 0.555 65.5 65.49 65.49

135 400 Rajgarh Nagda D/C 1 D/C 103 Twin Moose 0.00 45.35 -1 515 0.555 57.2 11.81 11.81

136 400 Rajgarh Nagda D/C 2 D/C 103 Twin Moose 0.00 45.35 -1 515 0.555 57.2 11.81 11.81

137 400 Satpura Seoni 1 S/C 147 Twin Moose 0.00 45.35 -1 515 0.555 81.6 36.23 36.23

138 400 Seoni Bhilai 1 S/C 154 Twin Moose 0.00 0.00 515 0.555 85.5 85.47 85.47

139 400 SSP Rajgarh-D/C 1 D/C 81 Twin Moose 0.00 0.00 515 0.555 45.0 44.96 44.96

140 400 SSP Rajgarh-D/C 2 D/C 81 Twin Moose 0.00 0.00 515 0.555 45.0 44.96 44.96

MAHARASHTRA

141 400 Akola Bhusawal 1 S/C 182.000 Twin Moose 0.00 45.35 -1 515 0.555 101.0 55.66 55.66

142 400 Aurangabad Bhusawal 1 S/C 238.000 Twin Moose 0.00 0.00 515 0.555 132.1 132.09 132.09

143 400 Babhaleshwar Aurangabad 1 S/C 125.000 Twin Moose 0.00 0.00 515 0.555 69.4 69.38 69.38

144 400 Babhaleshwar Padghe 1 D/C 170.000 Twin Moose 0.00 0.00 515 0.555 94.4 94.35 94.35

145 400 Babhaleshwar Padghe 2 D/C 170.000 Twin Moose 0.00 0.00 515 0.555 94.4 94.35 94.35

146 400 Bhusawal Babhaleshwar 1 S/C 222.000 Twin Moose 0.00 0.00 515 0.555 123.2 123.21 123.21

147 400 Chakan Pune (PG) 1 S/C 19.000 Twin Moose 0.00 0.00 515 0.555 10.5 10.55 10.55

148 400 Chandrapur Khaperkheda 1 S/C 148.000 Twin Moose 0.00 0.00 515 0.555 82.1 82.14 82.14

149 400 Chandrapur Parli Ckt I 1 S/C 357.000 Twin Moose 45.35 -1 45.35 -1 515 0.555 198.1 107.43 107.43

150 400 Chandrapur Parli Ckt II 1 D/C 357.000 Twin Moose 45.35 -1 45.35 -1 515 0.555 198.1 107.43 107.43


ANNEXURE 3


WESTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor (Yes=1,

No=-1)

SIL

Line

charging

Mvar/km

Total

Line

Charging

Mvar of

the line

MVAR

relief

available

when line is

opened

MVAR relief

available when

line is opened

& Line Reactor

is used as Bus

Reactor

*

Remarks

151 400 Chandrapur Parli Ckt III 2 D/C 357.000 Twin Moose 45.35 -1 45.35 -1 515 0.555 198.1 107.43 107.43

152 400 Dabhol Nagothane 1 D/C 137.000 Twin Moose 0.00 0.00 515 0.555 76.0 76.04 76.04

153 400 Dabhol Nagothane 2 D/C 137.000 Twin Moose 0.00 0.00 515 0.555 76.0 76.04 76.04

154 400 Dabhol New Koyna

(Quad)1 D/C 48.000 Twin Moose 0.00 0.00 515 0.555 26.6 26.64 26.64

155 400 Dabhol New Koyna

(Quad)2 D/C 48.000 Twin Moose 0.00 0.00 515 0.555 26.6 26.64 26.64

156 400 Dhule Babhaleshwar 1 D/C 170.000 Twin Moose 0.00 0.00 515 0.555 94.4 94.35 94.35

157 400 Dhule Babhaleshwar 2 D/C 170.000 Twin Moose 0.00 0.00 515 0.555 94.4 94.35 94.35

158 400 Dhule Sardar Sarovar 1 D/C 264 Twin Moose 0.00 0.00 515 0.555 146.5 146.52 146.52

159 400 Dhule Sardar Sarovar 2 D/C 264 Twin Moose 0.00 0.00 515 0.555 146.5 146.52 146.52

160 400 Jaigadh New Koyna 1 D/C 55.000 Twin Moose 0.00 0.00 515 0.555 30.5 30.53 30.53

161 400 Jaigadh New Koyna 2 D/C 55.000 Twin Moose 0.00 0.00 515 0.555 30.5 30.53 30.53

162 400 Jaigadh Karad 1 D/C 111.000 Twin Moose 0.00 0.00 515 0.555 61.6 61.61 61.61

163 400 Jaigadh Karad 2 D/C 111.000 Twin Moose 0.00 0.00 515 0.555 61.6 61.61 61.61

164 400 Jejuri Koyna IV 1 S/C 140.000 Twin Moose 0.00 0.00 515 0.555 77.7 77.70 77.70

165 400 Kalwa Kharghar 1 S/C 28.000 Twin Moose 0.00 0.00 515 0.555 15.5 15.54 15.54

166 400 Kalwa Lonikand 1 S/C 98.000 Twin Moose 0.00 0.00 515 0.555 54.4 54.39 54.39

167 400 Kalwa Padghe 1 S/C 56.000 Twin Moose 0.00 0.00 515 0.555 31.1 31.08 31.08

168 400 Karad New Koyna 1 D/C 72.000 Quad Moose 0.00 0.00 687 0.74 53.3 53.28 53.28

169 400 Karad New Koyna 2 D/C 72.000 Quad Moose 0.00 0.00 687 0.74 53.3 53.28 53.28

170 400 Karad Kolhapur 1 D/C 105.000 Twin Moose 0.00 0.00 515 0.555 58.3 58.28 58.28

171 400 Karad Kolhapur 2 D/C 105.000 Twin Moose 0.00 0.00 515 0.555 58.3 58.28 58.28

172 400 Khaperkheda Koradi 1 S/C 4.000 Twin Moose 0.00 0.00 515 0.555 2.2 2.22 2.22

173 400 Kharghar Padghe 1 S/C 86.000 Twin Moose 0.00 0.00 515 0.555 47.7 47.73 47.73

174 400 Koradi Bhusawal 1 S/C 344.000 Twin Moose 45.35 -1 45.35 -1 515 0.555 190.9 100.22 100.22

175 400 Koradi Akola 1 S/C 243.000 Twin Moose 45.35 -1 0.00 515 0.555 134.9 89.51 89.51

176 400 Lonikand Karad 1 S/C 161.000 Twin Moose 0.00 0.00 515 0.555 89.4 89.36 89.36

177 400 Lonikand Jejuri 1 S/C 100.000 Twin Moose 0.00 0.00 515 0.555 55.5 55.50 55.50

178 400 Lonikand Koyna-IV 1 S/C 211.000 Twin Moose 0.00 0.00 515 0.555 117.1 117.11 117.11

179 400 Lonikhand Chakan 1 S/C 25.000 Twin Moose 0.00 0.00 515 0.555 13.9 13.88 13.88

180 400 New Koyna Koyna stage IV 1 D/C 2.000 Twin Moose 0.00 0.00 515 0.555 1.1 1.11 1.11

181 400 New Koyna Koyna stage IV 2 D/C 2.000 Twin Moose 0.00 0.00 515 0.555 1.1 1.11 1.11


ANNEXURE 3


WESTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor (Yes=1,

No=-1)

SIL

Line

charging

Mvar/km

Total

Line

Charging

Mvar of

the line

MVAR

relief

available

when line is

opened

MVAR relief

available when

line is opened

& Line Reactor

is used as Bus

Reactor

*

Remarks

182 400 Padghe Nagothane 1 D/C 117.000 Twin Moose 0.00 0.00 515 0.555 64.9 64.94 64.94

183 400 Padghe Nagothane 2 D/C 117.000 Twin Moose 0.00 0.00 515 0.555 64.9 64.94 64.94

184 400 Parli Sholapur 1 S/C 182.000 Twin Moose 45.35 -1 0.00 515 0.555 101.0 55.66 55.66

185 400 Parli Lonikhand 1 D/C 284.000 Twin Moose 45.35 -1 45.35 -1 515 0.555 157.6 66.92 66.92

186 400 Parli Lonikhand 2 D/C 284.000 Twin Moose 45.35 -1 45.35 -1 515 0.555 157.6 66.92 66.92

187 400 Pune (PG) Padghe 1 S/C 96.000 Twin Moose 0.00 0.00 515 0.555 53.3 53.28 53.28

188 400 Sholapur(Mah) Sholapur(PG) 1 S/C 178.000 Twin Moose 0.00 0.00 515 0.555 98.8 98.79 98.79

189 400 Sholapur(PG) Karad 1 S/C 300.000 Twin Moose 0.00 45.35 -1 515 0.555 166.5 121.15 121.15

190 400 Asoj Ukai 1 S/C 140 Twin Moose 0.00 0.00 515 0.555 77.7 77.70 77.70

191 400 Mundra (Adani) Varsana 1 S/C 166 Twin Moose 0.00 0.00 515 0.555 92.1 92.13 92.13

192 400 Varsana Hadala 1 S/C 155 Twin Moose 0.00 0.00 515 0.555 86.0 86.03 86.03

193 400 Mundra (Adani) Hadala 1 S/C 238 Twin Moose 0.00 57.14 -1 515 0.555 132.1 74.95 74.95

194 400 Zerda Vadavi(R'chpur) D/C * 1 D/C 155 Twin Moose 0.00 0.00 515 0.555 86.0 86.03 86.03

195 400 Zerda Vadavi(R'chpur) D/C * 2 D/C 155 Twin Moose 0.00 0.00 515 0.555 86.0 86.03 86.03

196 400 Limbdi(Chorania) Vadavi(R'chpur) D/C * 1 D/C 190 Twin Moose 0.00 0.00 515 0.555 105.5 105.45 105.45

197 400 Limbdi(Chorania) Vadavi(R'chpur) D/C * 2 D/C 190 Twin Moose 0.00 0.00 515 0.555 105.5 105.45 105.45

198 400 Asoj Wanakbori 1 S/C 76 Twin Moose 0.00 0.00 515 0.555 42.2 42.18 42.18

199 400 Chorania Amreli 1 S/C 164 Twin Moose 0.00 0.00 515 0.555 91.0 91.02 91.02

200 400 Asoj Chorania 1 S/C 166 Twin Moose 0.00 0.00 515 0.555 92.1 92.13 92.13

201 400 Asoj Chorania 1 S/C 177 Twin Moose 0.00 0.00 515 0.555 98.2 98.24 98.24

202 400 Asoj SSP 1 S/C 83 Twin Moose 0.00 0.00 515 0.555 46.1 46.07 46.07

203 400 Kasor SSP 1 S/C 146 Twin Moose 0.00 0.00 515 0.555 81.0 81.03 81.03

204 400 Kasor GPEC 1 S/C 98 Twin Moose 0.00 0.00 515 0.555 54.4 54.39 54.39

205 400 Kasor-Chorania Chorania 1 S/C 103 Twin Moose 0.00 0.00 515 0.555 57.2 57.17 57.17

206 400 Amreli Jetpur 1 S/C 96 Twin Moose 0.00 0.00 515 0.555 53.3 53.28 53.28

207 400 Chorania Hadala 1 S/C 166 Twin Moose 0.00 0.00 515 0.555 92.1 92.13 92.13

208 400 Hadala Jetpur 1 S/C 115 Twin Moose 0.00 0.00 515 0.555 63.8 63.83 63.83

209 400 Soja Kansari 1 S/C 135 Twin Moose 0.00 0.00 515 0.555 74.9 74.93 74.93

210 400 Vadavi(R'chpur) Dehgam 1 S/C 62 Twin Moose 0.00 0.00 515 0.555 34.4 34.41 34.41

211 400 Vadavi(R'chpur) Dehgam 1 S/C 62 Twin Moose 0.00 0.00 515 0.555 34.4 34.41 34.41

212 400 Soja Wanakbori 1 S/C 95 Twin Moose 0.00 0.00 515 0.555 52.7 52.73 52.73

GUJARAT


ANNEXURE 3


WESTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor (Yes=1,

No=-1)

SIL

Line

charging

Mvar/km

Total

Line

Charging

Mvar of

the line

MVAR

relief

available

when line is

opened

MVAR relief

available when

line is opened

& Line Reactor

is used as Bus

Reactor

*

Remarks

213 Soja Dehgam 1 S/C 40 Twin Moose 0.00 0.00 515 0.555 22.2 22.20 22.20

214 400 Dehgam Wanakbori 1 S/C 67 Twin Moose 0.00 0.00 515 0.555 37.2 37.19 37.19

CHATTISGARH

215 400 Bhilai Korba(W) 1 S/C 190 Twin Moose 45.35 -1 0.00 515 0.555 105.5 60.10 60.10

216 400 Bhilai Seoni upto border 1 S/C 78 Twin Moose 45.35 -1 0.00 515 0.555 43.3 -2.06 -2.06

36060 2039.0 3329.0 22077.8 16709.8 20397.0

*

TOTAL

Utilization of line reactor as bus reactor necessitates arrangements for bypassing Neutral Grounding reactor(NGR) of line reactor. Work is in progress at many substations & this

column is therefore incomplete as of now


ANNEXURE 3


SOUTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length (in

km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when line

is opened & Line

Reactor is used as

Bus Reactor

Remarks

A. POWERGRID-SR1

1 400 ALMATHI VALLUR 1 D/C 40.000 TWIN MOOSE 0.00 0.00 515 0.555 22.2 22.20 22.20

2 400 ALMATHI VALLUR 2 D/C 40.000 TWIN MOOSE 0.00 0.00 515 0.555 22.2 22.20 22.20

3 400 GOOTY NELMANGALA 1 S/C 256.130 TWIN MOOSE 0.00 45.35 -1 515 0.555 142.2 96.80 96.80

4 400 HYDERABAD GAJWAL 1 S/C 72.800 TWIN MOOSE 45.35 -1 0.00 515 0.555 40.4 -4.95 -4.95

5 400 HYDERABAD KURNOOL 1 S/C 226.500 TWIN MOOSE 0.00 0.00 515 0.555 125.7 125.71 125.71

6 400 HYDERABAD NAGARJUNASAGAR 1 S/C 155.264 TWIN MOOSE 0.00 0.00 515 0.555 86.2 86.17 86.17

7 400 KHAMMAM NAGARJUNASAGAR 1 S/C 144.577 TWIN MOOSE 0.00 0.00 515 0.555 80.2 80.24 80.24

8 400 KHAMMAM VIJAYAWADA 1 S/C 114.775 TWIN MOOSE 0.00 0.00 515 0.555 63.7 63.70 63.70

9 400 KHAMMAM WARANGAL 1 S/C 117.500 TWIN MOOSE 45.35 -1 0.00 515 0.555 65.2 19.86 19.86

10 400 KURNOOL GOOTY 1 S/C 84.590 TWIN MOOSE 0.00 0.00 515 0.555 46.9 46.95 46.95

11 400 MALKARAM HYDERABAD 1 S/C 54.060 TWIN AAAC 0.00 45.35 -1 425 0.555 30.0 -15.35 -15.35

12 400 MEHBOOBNAGAR RAICHUR 1 S/C 73.680 TWIN MOOSE 0.00 0.00 515 0.555 40.9 40.89 40.89

13 400 NAGARJUNASAGAR CUDDAPAH 1 S/C 277.325 TWIN MOOSE 0.00 45.35 -1 515 0.555 153.9 108.56 108.56

14 400 NAGARJUNASAGAR CUDDAPAH 2 S/C 278.664 TWIN MOOSE 0.00 45.35 -1 515 0.555 154.7 109.31 109.31

15 400 NAGARJUNASAGAR GOOTY 1 S/C 308.437 TWIN MOOSE 45.35 1 45.35 -1 515 0.555 171.2 80.48 125.83

16 400NAGARJUNASAGAR MEHBOOBNAGAR 1 S/C 184.350 TWIN MOOSE

57.14 -1 0.00 515 0.555 102.3 45.17 45.17

17 NELLORE ALMATHI 1 D/C 194.450 TWIN MOOSE 0.00 0.00 515 0.555 107.9 107.92 107.92

18 400 NELLORE ALMATHI 2 D/C 194.450 TWIN MOOSE 0.00 0.00 515 0.555 107.9 107.92 107.92

19 400 RAICHUR GOOTY 1 D/C 146.720 QUAD BERSIMIS 0.00 0.00 691 0.746 109.5 109.45 109.45

20 400 RAICHUR GOOTY 2 D/C 146.720 QUAD BERSIMIS 0.00 0.00 691 0.746 109.5 109.45 109.45

21 400 RAICHUR MUNIRABAD 1 S/C 172.445 TWIN MOOSE 0.00 57.14 -1 515 0.555 95.7 38.56 38.56

22 400 RAMAGUNDAM CHANDRAPUR 1 D/C 177.605 TWIN MOOSE 0.00 0.00 515 0.555 98.6 98.57 98.57

23 400 RAMAGUNDAM CHANDRAPUR 2 D/C 177.605 TWIN MOOSE 0.00 0.00 515 0.555 98.6 98.57 98.57

24 400 RAMAGUNDAM GAJWAL 1 S/C 135.000 TWIN MOOSE 0.00 0.00 515 0.555 74.9 74.93 74.93

25 400 RAMAGUNDAM HYDERABAD 3 D/C 201.236 TWIN MOOSE 0.00 0.00 515 0.555 111.7 111.69 111.69

26 400 RAMAGUNDAM HYDERABAD 4 D/C 201.236 TWIN MOOSE 0.00 0.00 515 0.555 111.7 111.69 111.69

27 400 RAMAGUNDAM MALKARAM 1 S/C 192.400 TWIN AAAC 0.00 0.00 425 0.555 106.8 106.78 106.78

28 400 RAMAGUNDAM NAGARJUNASAGAR 1 D/C 267.200 TWIN MOOSE 45.35 -1 45.35 -1 515 0.555 148.3 57.59 57.59

29 400 RAMAGUNDAM NAGARJUNASAGAR 2 D/C 267.200 TWIN MOOSE 45.35 -1 45.35 -1 515 0.555 148.3 57.59 57.59

30 400 RAMAGUNDAM WARANGAL 1 S/C 98.830 TWIN MOOSE 0.00 0.00 515 0.555 54.9 54.85 54.85

31 400 SIMHADRI GAJUWAKA 1 S/C 12.800 TWIN MOOSE 0.00 57.14 1 515 0.555 7.1 -50.04 7.10


ANNEXURE 3


SOUTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length (in

km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when line

is opened & Line

Reactor is used as

Bus Reactor

Remarks

32 400 SIMHADRI GAJUWAKA 2 S/C 12.800 TWIN MOOSE 0.00 57.14 1 515 0.555 7.1 -50.04 7.10

33 400 VALLUR SRIPURUMPUDUR 1 D/C 104.300 TWIN MOOSE 0.00 0.00 515 0.555 57.9 57.89 57.89

34 400 VALLUR SRIPURUMPUDUR 2 D/C 104.300 TWIN MOOSE 0.00 0.00 515 0.555 57.9 57.89 57.89

35 400 VEMAGIRI SIMHADRI 1 S/C 193.500 TWIN MOOSE 0.00 0.00 515 0.555 107.4 107.39 107.39

36 400 VEMAGIRI SIMHADRI 2 S/C 193.500 TWIN MOOSE 0.00 0.00 515 0.555 107.4 107.39 107.39

37 400 VIJAYAWADA GAJUWAKA 3 D/C 314.718 TWIN MOOSE 57.14 1 57.14 1 515 0.555 174.7 60.38 174.67

38 400 VIJAYAWADA NELLORE 1 D/C 340.000 TWIN MOOSE 45.35 1 45.35 -1 515 0.555 188.7 98.00 143.35

39 400 VIJAYAWADA NELLORE 2 D/C 340.000 TWIN MOOSE 45.35 1 45.35 -1 515 0.555 188.7 98.00 143.35

40 400 VIJAYAWADA VEMAGIRI 3 D/C 195.410 TWIN MOOSE 45.35 1 0.00 515 0.555 108.5 63.10 108.45

41 400 VIJAYAWADA VEMAGIRI 4 D/C 195.410 TWIN MOOSE 57.14 1 0.00 515 0.555 108.5 51.31 108.45

A. POWERGRID-SR2

42 400 BANGALORE SALEM SC1 S/C 181.357 TWIN MOOSE 0.00 45.35 1 515 0.555 100.7 55.30 100.65

43 400 CHITOOR SRIPERUMBUDUR SC1 S/C 95.140 TWIN MOOSE 0.00 45.35 1 515 0.555 52.8 7.45 52.80

44 400 CUDDAPAH CHITOOR SC1 S/C 147.140 TWIN MOOSE 0.00 0.00 515 0.555 81.7 81.66 81.66

45 400 CUDDAPAH KOLAR AC SC1 S/C 174.073 TWIN MOOSE 0.00 0.00 515 0.555 96.6 96.61 96.61

46 400 GOOTY HOODY SC1 S/C 253.690 TWIN MOOSE 57.14 -1 0.00 515 0.555 140.8 83.66 83.66

47 400 HOSUR SALEM SC1 S/C 126.339 TWIN MOOSE 0.00 0.00 515 0.555 70.1 70.12 70.12

48 400 HASSAN MYSORE DC1 D/C 96.000 TWIN MOOSE 0.00 0.00 515 0.555 53.3 53.28 53.28

49 400 HASSAN MYSORE DC2 D/C 96.000 TWIN MOOSE 0.00 0.00 515 0.555 53.3 53.28 53.28

50 400 KAIGA NARENDRA DC1 D/C 107.662 AAAC TWIN 0.00 0.00 425 0.555 59.8 59.75 59.75

51 400 KAIGA NARENDRA DC2 D/C 107.662 AAAC TWIN 0.00 0.00 425 0.555 59.8 59.75 59.75

52 400 KAIGA SIRSI DC1 D/C 61.432 TWIN MOOSE 0.00 0.00 515 0.555 34.1 34.09 34.09

53 400 KAIGA SIRSI DC2 D/C 61.432 TWIN MOOSE 0.00 0.00 515 0.555 34.1 34.09 34.09

54 400 KALIVANDAPATTU SRIPERUMBUDUR SC1 S/C 30.700 TWIN MOOSE 0.00 0.00 515 0.555 17.0 17.04 17.04

55 400 KOLAR AC BANGALORE SC1 S/C 97.391 TWIN MOOSE 0.00 45.35 1 515 0.555 54.1 8.70 54.05

56 400 KOLAR AC HOODY DC1 D/C 51.067 QUAD BERSIMIS 0.00 0.00 691 0.746 38.1 38.10 38.10

57 400 KOLAR AC HOODY DC2 D/C 51.067 QUAD BERSIMIS 0.00 0.00 691 0.746 38.1 38.10 38.10

58 400 KOLAR AC HOSUR DC1 D/C 69.000 TWIN MOOSE 0.00 0.00 515 0.555 38.3 38.30 38.30

59 400 KOLAR AC HOSUR DC2 D/C 69.000 TWIN MOOSE 0.00 0.00 515 0.555 38.3 38.30 38.30

60 400 KOLAR AC KALIVANDAPATTU SC1 S/C 241.200 TWIN MOOSE 0.00 45.35 -1 515 0.555 133.9 88.51 88.51

61 400 KUDAMKULAM TIRUNELVELI DC1 D/C 72.489 QUAD MOOSE 0.00 0.00 687 0.740 53.6 53.64 53.64




ANNEXURE 3


SOUTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length (in

km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when line

is opened & Line

Reactor is used as

Bus Reactor

Remarks


65 400 MADURAI KARAIKUDI SC1 S/C 129.761 TWIN MOOSE 57.14 -1 0.00 515 0.555 72.0 14.87 14.87

66 400 MADURAI THIRUNELVELI DC1 D/C 161.700 TWIN MOOSE 0.00 0.00 515 0.555 89.7 89.74 89.74

67 400 MADURAI THIRUNELVELI DC2 D/C 161.700 TWIN MOOSE 0.00 0.00 515 0.555 89.7 89.74 89.74

68 400 MADURAI UDUMALPET SC1 S/C 127.232 TWIN MOOSE 0.00 0.00 515 0.555 70.6 70.61 70.61

69 400 NARENDRA DAVANGERE DC1 D/C 156.500 TWIN MOOSE 0.00 0.00 515 0.555 86.9 86.86 86.86

70 400 NARENDRA DAVANGERE DC2 D/C 156.500 TWIN MOOSE 0.00 0.00 515 0.555 86.9 86.86 86.86

71 400 NELAMANGALA BANGALORE DC1 D/C 42.004 TWIN MOOSE 0.00 0.00 515 0.555 23.3 23.31 23.31

72 400 NELAMANGALA BANGALORE DC2 D/C 42.004 TWIN MOOSE 0.00 0.00 515 0.555 23.3 23.31 23.31

73 400 NELAMANGALA BANGALORE SC1 S/C 53.695 TWIN MOOSE 0.00 57.14 1 515 0.555 29.8 -27.34 29.80

74 400 NELAMANGALA MYSORE DC1 D/C 132.897 TWIN MOOSE 0.00 0.00 515 0.555 73.8 73.76 73.76

75 400 NELAMANGALA MYSORE DC2 D/C 132.897 TWIN MOOSE 0.00 0.00 515 0.555 73.8 73.76 73.76

76 400 NEYVELI_TS1 TRICHY DC2 D/C 171.950 TWIN MOOSE 0.00 45.35 1 515 0.555 95.4 50.08 95.43

77 400 NEYVELI_TS2 NEYVELI_TS1 SC1 S/C 13.939 TWIN MOOSE 0.00 0.00 515 0.555 7.7 7.74 7.74

78 400 NEYVELI_TS2 PUDUCHERY SC1 S/C 68.000 TWIN MOOSE 0.00 0.00 515 0.555 37.7 37.74 37.74

79 400 NEYVELI_TS2 PUGALUR DC1 D/C 198.047 TWIN MOOSE 0.00 45.35 -1 515 0.555 109.9 64.56 64.56

80 400 NEYVELI_TS2 EXP PUGALUR SC1 SC1 199.670 TWIN MOOSE 0.00 45.35 -1 515 0.555 110.8 65.47 65.47

81 400 NEYVELI_TS2 SALEM SC1 S/C 199.670 TWIN MOOSE 0.00 0.00 515 0.555 110.8 110.82 110.82

82 400 NEYVELI_TS2 SALEM SC2 S/C 178.720 TWIN MOOSE 0.00 45.35 1 515 0.555 99.2 53.84 99.19

83 400 NEYVELI_TS2 TRICHY DC1 D/C 164.175 TWIN MOOSE 0.00 57.14 -1 515 0.555 91.1 33.97 33.97

84 400 PUDUCHERRY SUNGUVARCHATRA

MSC1 S/C 136.410 TWIN MOOSE 0.00 0.00 515 0.555 75.7 75.71 75.71

85 400 PUGALUR MADURAI DC1 D/C 123.643 TWIN MOOSE 0.00 0.00 515 0.555 68.6 68.62 68.62

86 400 PUGALUR MADURAI DC2 D/C 123.643 TWIN MOOSE 0.00 0.00 515 0.555 68.6 68.62 68.62

87 400 SALEM UDUMALPET SC1 S/C 150.543 TWIN MOOSE 0.00 45.35 1 515 0.555 83.6 38.20 83.55

88 400 SALEM UDUMALPET SC2 S/C 137.910 TWIN MOOSE 0.00 57.14 1 515 0.555 76.5 19.40 76.54

89 400SUNGUVARCHATRAM SRIPERUMBUDDUR SC1 S/C 17.900 TWIN MOOSE

0.00 45.35 1 515 0.555 9.9 -35.42 9.93

90 400 THIRUNELVELI TRIVANDRUM DC1 D/C 160.400 TWIN MOOSE 0.00 57.14 -1 515 0.555 89.0 31.88 31.88

91 400 THIRUNELVELI TRIVANDRUM DC2 D/C 160.400 TWIN MOOSE 0.00 0.00 515 0.555 89.0 89.02 89.02

92 400 THIRUNELVELI UDUMALPET DC1 D/C 264.987 TWIN MOOSE 57.14 1 57.14 1 515 0.555 147.1 32.78 147.07

93 400 THIRUNELVELI UDUMALPET DC2 D/C 264.987 TWIN MOOSE 57.14 1 57.14 1 515 0.555 147.1 32.78 147.07

94 400 TRICHY KARAIKUDI SC1 S/C 97.699 TWIN MOOSE 0.00 0.00 515 0.555 54.2 54.22 54.22

95 400 TRICHY MADURAI DC1 D/C 130.486 TWIN MOOSE 0.00 45.35 1 515 0.555 72.4 27.07 72.42

96 400 UDUMALPET ARASUR DC1 D/C 65.116 TWIN MOOSE 0.00 0.00 515 0.555 36.1 36.14 36.14


ANNEXURE 3


SOUTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length (in

km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when line

is opened & Line

Reactor is used as

Bus Reactor

Remarks

97 400 UDUMALPET ARASUR DC2 D/C 65.116 TWIN MOOSE 0.00 0.00 515 0.555 36.1 36.14 36.14

98 400 UDUMALPET TRICHUR DC1 D/C 129.793 TWIN MOOSE 0.00 45.35 1 515 0.555 72.0 26.68 72.04

99 400 UDUMALPET TRICHUR DC2 D/C 129.793 TWIN MOOSE 0.00 45.35 1 515 0.555 72.0 26.68 72.04

100 400 TRICHUR KOCHI DC1 # D/C 78.200 TWIN MOOSE 0.00 0.00 515 0.555 43.4 43.40 43.40

101 400 TRICHUR KOCHI DC2 # D/C 78.200 TWIN MOOSE 0.00 0.00 515 0.555 43.4 43.40 43.40

102 400 KALPAKKA GAZUWAKA 1 D/C 12.000 TWIN MOOSE 0.00 0.00 515 0.555 6.7 6.66 6.66

103 400 KALPAKKA GAZUWAKA 2 D/C 12.000 TWIN MOOSE 0.00 0.00 515 0.555 6.7 6.66 6.66

104 400 KALPAKKA VEMAGIRI 1 D/C 158.000 TWIN MOOSE 0.00 0.00 515 0.555 87.7 87.69 87.69

105 400 KALPAKKA VEMAGIRI 2 D/C 158.000 TWIN MOOSE 0.00 0.00 515 0.555 87.7 87.69 87.69

106 400 KHAMMAM KALPAKKA 1 D/C 364.000 TWIN MOOSE 57.14 1 57.14 -1 515 0.555 202.0 87.73 144.88

107 400 KHAMMAM KALPAKKA 2 D/C 364.000 TWIN MOOSE 57.14 1 57.14 -1 515 0.555 202.0 87.73 144.88

108 400 KHAMMAM MAMIDAPALLY 1 D/C 198.000 TWIN MOOSE 0.00 0.00 515 0.555 109.9 109.89 109.89

109 400 KHAMMAM MAMIDAPALLY 2 D/C 198.000 TWIN MOOSE 0.00 0.00 515 0.555 109.9 109.89 109.89

110 400 MAMIDIPALLY GHANAPUR S/C 45.000 TWIN MOOSE 0.00 0.00 515 0.555 25.0 24.98 24.98

111 400 RAMAGUNDAM DICHPALLY 1 D/C 149.000 TWIN MOOSE 0.00 0.00 515 0.555 82.7 82.70 82.70

112 400 SIMHADRI KALPAKKA 1 D/C 3.700 TWIN MOOSE 0.00 0.00 515 0.555 2.1 2.05 2.05




116 400 SRISAILAM KURNOOL S/C 104.000 TWIN MOOSE 0.00 0.00 515 0.555 57.7 57.72 57.72

117 400 SRISAILAM MAMIDAPALLI 1 D/C 147.000 TWIN MOOSE 0.00 0.00 515 0.555 81.6 81.59 81.59

118 400 SRISAILAM MAMIDAPALLI 2 D/C 147.000 TWIN MOOSE 0.00 0.00 515 0.555 81.6 81.59 81.59

119 400 SRISAILAM VTPS IV 1 D/C 213.000 TWIN MOOSE 0.00 0.00 515 0.555 118.2 118.22 118.22

120 400 SRISAILAM VTPS IV 2 D/C 213.000 TWIN MOOSE 0.00 0.00 515 0.555 118.2 118.22 118.22

121 400 VTPS IV VIJAYAWADA 1 D/C 18.660 TWIN MOOSE 0.00 0.00 515 0.555 10.4 10.36 10.36

122 400 VTPS IV VIJAYAWADA 1 D/C 18.660 TWIN MOOSE 0.00 0.00 515 0.555 10.4 10.36 10.36

123 400 VEMAGIRI GMR 1 D/C 1.760 TWIN MOOSE 0.00 0.00 515 0.555 1.0 0.98 0.98

124 400 VEMAGIRI GMR 2 D/C 1.760 TWIN MOOSE 0.00 0.00 515 0.555 1.0 0.98 0.98

125 400 VEMAGIRI GOUTAMI CCPP 1 D/C 39.000 TWIN MOOSE 0.00 0.00 515 0.555 21.6 21.65 21.65

126 400 VEMAGIRI GOUTAMI CCPP 2 D/C 39.000 TWIN MOOSE 0.00 0.00 515 0.555 21.6 21.65 21.65

127 400 VEMAGIRI GVK(JPD) 1 D/C 6.840 TWIN MOOSE 0.00 0.00 515 0.555 3.8 3.80 3.80

128 400 VEMAGIRI GVK(JPD) 2 D/C 6.840 TWIN MOOSE 0.00 0.00 515 0.555 3.8 3.80 3.80

APTRANSCO


ANNEXURE 3


SOUTHERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length (in

km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End

Shunt

Reactor

rated for

400kV

To End

reactor used

as Bus

Reactor

(Yes=1, No=-

1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when line

is opened & Line

Reactor is used as

Bus Reactor

Remarks

129 400 VEMAGIRI KONASEEMA 1 D/C 26.010 TWIN MOOSE 0.00 0.00 515 0.555 14.4 14.44 14.44

130 400 VEMAGIRI KONASEEMA 2 D/C 26.010 TWIN MOOSE 0.00 0.00 515 0.555 14.4 14.44 14.44

131 400 VIJAYAWADA VEMAGIRI 1 D/C 195.410 TWIN MOOSE 0.00 0.00 515 0.555 108.5 108.45 108.45

132 400 VIJAYAWADA VEMAGIRI 2 D/C 195.410 TWIN MOOSE 0.00 0.00 515 0.555 108.5 108.45 108.45

133 400 WARANGAL BOOPALAPPALLI 1 D/C 45.620 TWIN MOOSE 0.00 0.00 515 0.555 25.3 25.32 25.32

134 400 WARANGAL BOOPALAPPALLI 2 D/C 45.620 TWIN MOOSE 0.00 0.00 515 0.555 25.3 25.32 25.32

135 400 BTPS JSW TORANAGALLU 1 S/C 14.000 TWIN MOOSE 45.35 -1 0.00 515 0.555 7.8 -37.58 -37.58

136 400 JSW TORANAGALLU GUTTUR 1 S/C 146.000 TWIN MOOSE 0.00 45.35 1 515 0.555 81.0 35.68 81.03

137 400 GUTTUR HIRIYUR 1 D/C 100.000 DRAKE 45.35 1 0.00 515 0.555 55.5 10.15 55.50

138 400 GUTTUR HIRIYUR 2 D/C 100.000 DRAKE 45.35 1 0.00 515 0.555 55.5 10.15 55.50

139 400 HASSAN NELMANGALA 1 * D/C 213.000 TWIN MOOSE 0.00 45.35 1 515 0.555 118.2 72.86 118.22

140 400 HIRIYUR NELMANGALA 1 D/C 160.000 DRAKE 0.00 45.35 1 515 0.555 88.8 43.45 88.80

141 400 HIRIYUR NELMANGALA 2 D/C 160.000 DRAKE 0.00 45.35 1 515 0.555 88.8 43.45 88.80

142 400 HOODY NELMANGALA S/C 70.000 TWIN MOOSE 0.00 0.00 515 0.555 38.9 38.85 38.85

143 400 MUNIRABAD GUTTUR S/C 118.000 TWIN MOOSE 0.00 0.00 515 0.555 65.5 65.49 65.49

144 400 RAICHUR BTPS S/C 151.400 TWIN MOOSE 0.00 0.00 515 0.555 84.0 84.03 84.03

145 400 TALAGUPPA HASSAN 1 * D/C 284.000 TWIN MOOSE 45.35 1 0.00 515 0.555 157.6 112.27 157.62

146 400 TALAGUPPA NELMANGALA 2 D/C 350.000 TWIN MOOSE 45.35 1 45.35 1 515 0.555 194.3 103.55 194.25

147 400 NEYVELI_TS2 NEYVELI_TS2 EXP 1 S/C 1.400 TWIN MOOSE 0.00 0.00 515 0.555 0.8 0.78 0.78

19267 1103.9 1910.2 10825.2 7811.1 9597.1

NLC

TOTAL

KPTCL


ANNEXURE 3


EASTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End reactor

used as Bus

Reactor (Yes=1,

No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor

(Yes=1, No=-1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

*

Remarks

1 400 ARAMBAGH BIDHANNAGAR (WB) 1 80 Twin Moose 0.00 0.00 515 0.555 44.4 44.40 44.40

2 400 BAKRESWAR ARAMBAGH 1 130 Twin Moose 45.35 -1 0.00 515 0.555 72.2 26.80 26.80

3 400 BARIPADA PG KOLAGHAT (WB) 1 174 Twin Moose 0.00 0.00 515 0.555 96.6 96.57 96.57

4 400 DSTPS MEZIA 1 32 Twin Moose 0.00 0.00 515 0.555 17.8 17.76 17.76

5 400 INDRAVATI (PG) INDRAVATI (OHPC) 1 1 Twin Moose 0.00 0.00 515 0.555 0.6 0.56 0.56

6 400 JEERAT BAKRESWAR 1 162 Twin Moose 45.35 -1 0.00 515 0.555 89.9 44.56 44.56

7 400 KTPP JEERAT 1 130 Twin Moose 0.00 0.00 515 0.555 72.2 72.15 72.15

8 400 KTPS ARAMBAGH 1 75 Twin Moose 0.00 0.00 515 0.555 41.6 41.63 41.63

9 400 MERAMUNDALI MENDHASAL 1 90 Twin Moose 0.00 0.00 515 0.555 50.0 49.95 49.95 CHARGED AT 220KV

10 400 MERAMUNDALI MENDHASAL I 1 100 Twin Moose 0.00 0.00 515 0.555 55.5 55.50 55.50

11 400 PARULIA(PG) BIDHANNAGAR (WB) 1 11 Twin Moose 45.35 -1 0.00 515 0.555 6.1 -39.25 -39.25 CHARGED AT 220KV

12 400 PATRATU TENUGHAT 1 53 Twin Moose 0.00 0.00 515 0.555 29.4 29.42 29.42 CHARGED AT 220KV

13 400 PPSP ARAMBAGH 1 210 Twin Moose 0.00 0.00 515 0.555 116.6 116.55 116.55

14 400 PPSP ARAMBAGH 2 210 Twin Moose 0.00 0.00 515 0.555 116.6 116.55 116.55

15 400 PPSP BIDHANNAGAR (WB) 1 185 Twin Moose 0.00 0.00 515 0.555 102.7 102.68 102.68

16 400 RENGALI BARIPADA 1 240 Twin Moose 57.14 -1 0.00 515 0.555 133.2 76.06 76.06

17 400 BARIPADA MENDHASAL 1 273 Twin Moose 57.14 -1 0.00 515 0.555 151.5 94.37 94.37

18 400 BARIPADA MENDHASAL 2 273 Twin Moose 57.14 -1 0.00 515 0.555 151.5 94.37 94.37

CENTRAL SECTOR

19 400 BARH PATNA I 1 94 Quad Moose 0.00 45.35 -1 687 0.740 69.6 24.21 24.21

20 400 BARH PATNA II 1 94 Quad Moose 0.00 45.35 -1 687 0.740 69.6 24.21 24.21

21 400 BIHARSHARIFF MUZAFFARPUR 2 130 Twin Moose 0.00 0.00 515 0.555 72.2 72.15 72.15

22 400 BIHARSHARIFF SASARAM - I 1 195 Twin Moose 0.00 57.14 -1 515 0.555 108.2 51.08 51.08

23 400 BIHARSHARIFF SASARAM - II 2 195 Twin Moose 0.00 57.14 -1 515 0.555 108.2 51.08 51.08

24 400 BIHARSHARIFF (BSEB) TENUGHAT (JSEB) 1 182 Twin Moose 0.00 45.35 -1 515 0.555 101.0 55.66 55.66 CHARGED AT 220KV

25 400 FARAKKA KAHALGAON - I 1 95 Twin Moose 0.00 0.00 515 0.555 52.7 52.73 52.73

26 400 FARAKKA KAHALGAON - II 2 95 Twin Moose 0.00 0.00 515 0.555 52.7 52.73 52.73

27 400 FARAKKA KAHALGAON - III 1 95 Twin Moose 0.00 0.00 515 0.555 52.7 52.73 52.73

28 400 FARAKKA KAHALGAON - IV 2 95 Twin Moose 0.00 0.00 515 0.555 52.7 52.73 52.73

29 400 FARAKKA JEERAT 1 238 Twin Moose 0.00 45.35 -1 515 0.555 132.1 86.74 86.74

30 400 FARAKKA SAGARDIH 1 67 Twin Moose 0.00 0.00 515 0.555 37.2 37.19 37.19

31 400 FRAKKA MALDA 1 40 Twin Moose 0.00 0.00 515 0.555 22.2 22.20 22.20

STATE SECTOR


ANNEXURE 3


EASTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End reactor

used as Bus

Reactor (Yes=1,

No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor

(Yes=1, No=-1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

*

Remarks

32 400 FRAKKA MALDA 2 40 Twin Moose 0.00 0.00 515 0.555 22.2 22.20 22.20

33 400 FRAKKA PARULIA-I 1 150 Twin Moose 45.35 -1 0.00 515 0.555 83.3 37.90 37.90

34 400 FRAKKA PARULIA-II 1 146 Twin Moose 0.00 0.00 515 0.555 81.0 81.03 81.03

35 400 INDRAVATI RENGALI 1 356 Twin Moose 45.35 -1 45.35 -1 515 0.555 197.6 106.88 106.88

36 400 JAMSHEDPUR ROURKELA - I 1 174 Twin Moose 0.00 45.35 -1 515 0.555 96.6 51.22 51.22

37 400 JAMSHEDPUR ROURKELA - II 2 174 Twin Moose 0.00 45.35 -1 515 0.555 96.6 51.22 51.22

38 400 JEYPORE INDRAVATI 1 72 Twin Moose 0.00 0.00 515 0.555 40.0 39.96 39.96

39 400 JEYPORE MERAMUNDALI (OPTCL) 1 456 Twin Moose 72.56 -1 72.56 1 515 0.555 253.1 107.96 180.52

40 400 KAHALGAON BIHARSHARIFF - I 1 201 Twin Moose 0.00 45.35 -1 515 0.555 111.6 66.20 66.20

41 400 KAHALGAON BIHARSHARIFF - II 2 201 Twin Moose 0.00 45.35 -1 515 0.555 111.6 66.20 66.20

42 400 KAHALGAON BIHARSHARIFF - III 1 166 Twin Moose 0.00 0.00 515 0.746 123.8 123.84 123.84

43 400 KAHALGAON BIHARSHARIFF - IV 2 166 Twin Moose 0.00 0.00 515 0.746 123.8 123.84 123.84

44 400 KAHALGAON PATNA I 1 257 Quad Moose 0.00 45.35 -1 687 0.740 190.2 144.83 144.83

45 400 KhSTPP BARH 1 217 Quad Moose 0.00 0.00 687 0.740 160.6 160.58 160.58

46 400 MAITHON JAMSHEDPUR - II 1 153 Twin Moose 0.00 0.00 515 0.555 84.9 84.92 84.92

47 400 MAITHON KHALGAON - I 1 172 Twin Moose 45.35 -1 0.00 515 0.555 95.5 50.11 50.11

48 400 MAITHON KHALGAON - II 2 172 Twin Moose 45.35 -1 0.00 515 0.555 95.5 50.11 50.11

49 400 MAITHON RANCHI I 1 200 Twin Moose 45.35 -1 45.35 -1 515 0.555 111.0 20.30 20.30

50 400 MAITHON RANCHI II 2 200 Twin Moose 45.35 -1 45.35 -1 515 0.555 111.0 20.30 20.30

51 400 MAITHON MEZIA 1 84 Twin Moose 0.00 0.00 515 0.555 46.6 46.62 46.62

52 400 MAITHON MAITHON RB 2 31 Twin Moose 0.00 0.00 515 0.555 17.2 17.21 17.21

53 400 MALBASE BINAGURI 1 125.1 Twin Moose 0.00 0.00 515 0.555 69.4 69.43 69.43

54 400 MALDA PURNEA I 1 167 Twin Moose 57.14 -1 0.00 515 0.555 92.7 35.54 35.54

55 400 MALDA PURNEA II 2 167 Twin Moose 57.14 -1 0.00 515 0.555 92.7 35.54 35.54

56 400 MEJIA JAMSHEDPUR I 1 168 Twin Moose 0.00 0.00 515 0.555 93.2 93.24 93.24

57 400 PARULIA JAMSHEDPUR 1 177 Twin Moose 0.00 0.00 515 0.555 98.2 98.24 98.24

58 400 PURNEA BINAGURI - I 1 168 Twin Moose 57.14 -1 0.00 515 0.555 93.2 36.10 36.10

59 400 PURNEA BINAGURI - II 2 168 Twin Moose 57.14 -1 0.00 515 0.555 93.2 36.10 36.10

60 400 PURNEA BINAGURI - III 1 160 Quad Moose 0.00 0.00 687 0.740 118.4 118.40 118.40

61 400 PURNEA BINAGURI - IV 2 160 Quad Moose 0.00 0.00 687 0.740 118.4 118.40 118.40

62 400 PURNEA MUZAFFARPUR 1 240 Quad Moose 57.14 -1 57.14 -1 687 0.740 177.6 63.31 63.31

63 400 PURNEA MUZAFFARPUR 2 240 Quad Moose 57.14 -1 57.14 -1 687 0.740 177.6 63.31 63.31

64 400 RANCHI ROURKELA 2 145 Twin Moose 0.00 0.00 515 0.555 80.5 80.48 80.48

65 400 SUBHASGRAM(PG) JEERAT(WB) 1 70 Twin Moose 0.00 0.00 515 0.555 38.9 38.85 38.85

66 400 TALA BINAGURI I 1 115 Twin Moose 0.00 57.14 1 515 0.555 63.8 6.68 63.83


ANNEXURE 3


EASTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Tower)

Line

Length

(in km)

Type of

conductor

From End

Shunt

Reactor

rated for

400kV

From End reactor

used as Bus

Reactor (Yes=1,

No=-1)

To End

Shunt

Reactor

rated for

400kV

To End reactor

used as Bus

Reactor

(Yes=1, No=-1)

SIL

Line

charging

Mvar/km

Total Line

Charging

Mvar of the

line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

*

Remarks

67 400 TALA BINAGURI II 2 115 Twin Moose 0.00 57.14 1 515 0.555 63.8 6.68 63.83

68 400 TALA BINAGURI-IV 4 98 Twin Moose 0.00 57.14 1 515 0.555 54.4 -2.70 54.45

69 400 TEESTA-V BINAGURI 1 115 Twin Moose 0.00 0.00 515 0.555 63.8 63.83 63.83

70 400 TSTPP ROURKELA - I 1 171 Twin Moose 45.35 0.00 515 0.555 94.9 49.55 94.91

71 400 TSTPP ROURKELA - II 2 171 Twin Moose 45.35 0.00 515 0.555 94.9 49.55 94.91

72 400 TSTPP RENGALI - I 1 24 Twin Moose 0.00 0.00 515 0.555 13.3 13.32 13.32

73 400 TSTPP RENGALI - II 2 24 Twin Moose 0.00 0.00 515 0.555 13.3 13.32 13.32

74 400 TSTPP (NTPC) MERAMUNDALI (OPTCL) 1 51 Twin Moose 0.00 0.00 515 0.555 28.3 28.31 28.31

10871 1085.7 1016.8 6367.4 4264.9 4599.6

*

TOTAL

Utilization of line reactor as bus reactor necessitates arrangements for bypassing Neutral Grounding reactor(NGR) of line reactor. Work is in progress at many substations & this column is

therefore incomplete as of now


ANNEXURE 3


NORTH EASTERN REGION

Sl.

No

Voltage

in kVFROM TO

CKT

ID

Ckt. Type

(Towers)

Line

Length

(in km)

Type of

conductor

From End

Shunt Reactor

rated for

400kV

From End

reactor used as

Bus Reactor

(Yes=1, No=-1)

To End Shunt

Reactor rated

for 400kV

To End reactor

used as Bus

Reactor

(Yes=1, No=-1)

SILLine

charging

Mvar/km

Total Line

Charging

Mvar of

the line

MVAR relief

available

when line is

opened

MVAR relief

available when

line is opened &

Line Reactor is

used as Bus

Reactor

Remarks

A. POWERGRID

1 400 BALIPARA BONGAIGAON 1 D/C 289.72 Twin Moose 57.14 -1 45.35 -1 515 0.555 160.8 58.30 58.30

2 400 BALIPARA BONGAIGAON 2 D/C 289.72 Twin Moose 57.14 -1 45.35 -1 515 0.555 160.8 58.30 58.30

3 400 BALIPARA RANGANADI (NEEPCO) 1 D/C 166.34 Twin Moose 45.35 1 45.35 -1 515 0.555 92.3 1.62 46.97

4 400 BALIPARA RANGANADI (NEEPCO) 2 D/C 166.34 Twin Moose 45.35 1 45.35 -1 515 0.555 92.3 1.62 46.97

5 400 BALIPARA MISA 1 D/C 95.41 Twin Moose 45.35 -1 0.00 0 515 0.555 53.0 7.60 7.60

6 400 BALIPARA MISA 2 D/C 95.41 Twin Moose 0.00 0 0.00 0 515 0.555 53.0 52.95 52.95

1103 250.3 181.4 612.1 180.4 271.1

TOTAL


ANNEXURE 4

400 and 765kV REACTORS INSTALLED CAPACITY-ALL INDIA LEVEL

NO. OF

REACTOR

TOTAL

MVAR

NO. OF

REACTOR

TOTAL

MVAR

NO. OF

REACTOR

TOTAL

MVAR

NO. OF

REACTOR

TOTAL

MVAR

NO. OF

REACTOR

TOTAL

MVAR

NO. OF

REACTOR

TOTAL

MVAR

NO. OF

REACTOR

TOTAL

MVAR

NO. OF

REACTOR

TOTAL

MVAR

NO. OF

REACTOR

TOTAL

MVAR

NO. OF

REACTOR

TOTAL

MVAR

1 240 0 0 0 0 1 240 2 480 0 0 0 0 0 0 0 0 0 0 0 0 720

2 100 0 0 1 110 0 0 0 0 0 0 0 0 0 0 0 0 2 200 0 0 310

3 125 5 625 0 0 2 250 0 0 0 0 0 0 1 125 0 0 0 0 0 0 1000

4 93 1 93 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 93

5 90 0 0 0 0 1 90 0 0 0 0 0 0 0 0 0 0 0 0 0 0 90

6 80 11 880 10 800 9 720 10 800 3 240 2 160 3 240 5 400 0 0 0 0 4240

7 72 0 0 1 72 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 72

8 63 6 378 20 1260 7 441 14 882 13 819 21 1323 3 189 24 1512 0 0 6 378 7182

9 50 26 1300 83 4150 20 1000 83 4150 9 450 43 2150 16 800 21 1050 5 250 8 400 15700

10 40 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

11 31.5 0 0 0 0 0 0 0 0 0 0 0 0 2 63 0 0 0 0 0 0 63

12 25 1 25 0 0 12 300 0 0 0 0 0 0 0 0 0 0 0 0 0 0 325

13 20 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 40 0 0 40

14 12.5 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 50 0 0 50

15 16.67 0 0 0 0 0 0 0 0 3 50.01 0 0 0 0 0 0 0 0 0 0 50.01

16 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 4 0 0 4

TOTAL 50 3301 115 6392 52 3041 109 6312 28 1559 66 3633 25 1417 50 2962 15 544 14 778 29939.01

TOTAL

MVAR

TOTAL

MVAR

TOTAL

MVAR

1 3301 6392 9693

2 3041 6312 9353

3 1559 3633 5192.01

4 1417 2962 4379

5 544 778 1322

6 9862 20077 29939524ALL INDIA

Sl.

No

Region

(A)

66

50

14

LINE REACTOR

165

161109

50

170 354

75

29

SUMMARY OF REACTORS

94

BUS REACTOR LINE REACTOR

NO. OF REACTOR

TOTAL

TOTAL NO. OF

REACTOR

North Eastern

28

25

115Northern

Western

Southern

Eastern

52

15

NO. OF REACTOR

NORTH EASTERN REGIONEASTERN REGION


WESTERN REGION SOUTHERN REGION

BUS REACTOR LINE REACTOR BUS REACTOR

400 & 765kV REACTORS INSTALLED CAPACITY

Sl.

No

REACTOR

CAAPCITY

IN MVAR

LINE REACTOR

NORTHERN REGION


TOTAL

REACTOR

CAPACITY IN

MVAR

BUS REACTOR


ANNEXURE 5

FAULT LEVEL OF SUBSTATIONS

MVA KA MVA KA MVA KA MVA KA

1 AKOLA 8357 12 8417 12 8326 12 8648 12

2 AMRELI 4596 7 4739 7 4371 6 4775 7

3 ASOJ 14532 21 15660 23 12771 18 16585 24

4 AURANGABAD 7636 11 7743 11 7531 11 7884 11

5 BABLESHWAR 12202 18 12610 18 11713 17 12935 19

6 BHADRAWATI 16698 24 16797 24 16785 24 17161 25

7 BHATAPARA 9412 14 9512 14 8935 13 8993 13

8 BHILAI 21664 31 22040 32 20999 30 21631 31

9 BHOPAL 12578 18 12841 19 11053 16 13928 20

10 BHUSAWAL 7828 11 7903 11 7905 11 8256 12

11 BINA 13082 19 13377 19 11631 17 14360 21

12 BINA-PG 13120 19 13415 19 11650 17 14401 21

13 BIRSINGPUR 6196 9 6325 9 5932 9 6518 9

14 BOISAR 13868 20 14531 21 14340 21 14862 21

15 CHANDRAPUR 18272 26 18394 27 18334 26 18795 27

16 CHORANIA 11270 16 11973 17 7660 11 10699 15

17 DABHOL 12963 19 14687 21 16392 24 17316 25

18 DAMOH 6368 9 6472 9 4969 7 5805 8

19 DEHGAM 14295 21 15760 23 12119 17 18848 27

20 DHULE 10680 15 11130 16 8262 12 11520 17

21 GANDHAR 12747 18 14363 21 9742 14 15181 22

22 GPEC 11320 16 12662 18 9131 13 13377 19

23 GWALIOR 10409 15 10547 15 10182 15 10856 16

24 HADALA 6420 9 6689 10 6227 9 6899 10

25 INDIRASAGAR 8448 12 8938 13 7321 11 11441 17

26 INDORE 11803 17 12190 18 10222 15 14172 20

27 ITARSI 14467 21 14792 21 14224 21 16717 24

28 JABALPUR 9700 14 9879 14 10184 15 10711 15

29 JAIGAD 6991 10 7581 11 10658 15 11309 16

30 JEJURI 8004 12 8593 12 8462 12 8812 13

31 JETPUR 4904 7 5069 7 4778 7 5216 8

32 JINDAL-B1 5780 8 5790 8 7286 11 7306 11

33 JINDAL-B2 2943 4 2958 4 6900 10 6917 10

34 KALWA 15019 22 16923 24 16716 24 17955 26

35 KARAD 10338 15 11900 17 11559 17 12299 18

36 KASOR 9903 14 10734 15 5885 8 11026 16

37 KATNI 4955 7 5043 7 5283 8 5512 8

38 KHANDWA 9975 14 10179 15 7933 11 12048 17

39 KHAPARKHEDA 13794 20 13914 20 12162 18 12701 18

40 KHARGHAR 11831 17 13097 19 13001 19 13820 20

41 KOLHAPUR 6731 10 7266 10 7148 10 7389 11

42 KORADI 14875 21 15021 22 13828 20 14587 21

43 KORBA NTPC 20980 30 21820 31 25119 36 25365 37

44 KORBA(W) 15920 23 16875 24 18061 26 18163 26

45 KOYNA 11649 17 14935 22 14504 21 16469 24

STATION NAMESl.No

MONSOON OFF PEAK MONSOON PEAK WINTER OFF PEAK WINTER PEAK

WESTERN REGION

NLDC 2012 REACTIVE POWER MANAGEMENT-a resource handbook 1 of 7

ANNEXURE 5



46 LANCO PATHADI 10141 15 10276 15 10716 15 10760 16

47 LONIKHAND 12232 18 13478 19 13178 19 14028 20

48 MAPUSA 4150 6 4291 6 4266 6 4330 6

49 MUNDRA 7715 11 8441 12 8579 12 9196 13

50 NAGDA 9334 13 9359 14 7626 11 12726 18

51 NAGOTHANE 10459 15 11263 16 11492 17 11918 17

52 NEW KOYNA 12937 19 16231 23 16035 23 17859 26

53 NSPCL 18770 27 19000 27 19329 28 20049 29

54 PADGHE 18019 26 19935 29 19595 28 21049 30

55 PARLI 9286 13 9524 14 8928 13 9807 14

56 PIRANA(T) 4308 6 4376 6 -- -- 11698 17

57 PIRANA_PG 4240 6 4307 6 7735 11 12109 17

58 RAIGARH 15827 23 15951 23 17273 25 17645 25

59 RAIPUR 23634 34 24041 35 24458 35 25684 37

60 RAJGARH 7097 10 7208 10 3365 5 9401 14

61 RANCHODPURA 10386 15 11078 16 7922 11 10054 15

62 SAMI 5602 8 6563 9 6381 9 7212 10

63 SATNA 9470 14 9739 14 9673 14 10663 15

64 SATPURA 12843 19 13030 19 12925 19 13825 20

65 SEONI (400) 14106 20 14219 21 12883 19 14785 21

66 SEONI (765) 12392 9 12420 9 11409 9 12769 10

67 SHOLAPUR 5335 8 5478 8 5219 8 5569 8

68 SIPAT (400) 11866 17 11629 17 9501 14 11766 17

69 SIPAT (765) 12636 10 12522 9 11270 9 12723 10

70 SOJA 11322 16 12136 18 10543 15 13366 19

71 SSP 11815 17 13570 20 7551 11 14151 20

72 SUGEN 15869 23 16818 24 13172 19 17054 25

73 TARAPUR APS 14341 21 15037 22 14886 21 15426 22

74 UKAI 4629 7 4744 7 4518 7 4806 7

75 VAPI 8611 12 8821 13 8490 12 8852 13

76 VINDHYACHAL (W) 15800 23 16024 23 19299 28 19750 29

77 WANAKBORI 12672 18 13389 19 11504 17 14546 21

78 WARDHA 6640 10 6658 10 6530 9 6754 10

79 ZERDA 6572 9 6732 10 6497 9 6862 10

80 ARAMBAG 10903 16 12078 17 10816 16 11905 17

81 BAKRESHWAR 7674 11 7906 11 7484 11 7865 11

82 BARH 5880 8 5933 9 8233 12 8388 12

83 BARIPADA 6975 10 7064 10 6987 10 7103 10

84 BIDHAN NAGAR 13013 19 14433 21 12936 19 14227 21

85 BIHARSHARIFF 15663 23 15832 23 16457 24 16836 24

86 BINAGURI 11323 16 11381 16 9122 13 9760 14

87 DURGAPUR STPS 6620 10 6594 10 6564 9 6602 10

88 FARAKKA 21605 31 22057 32 21348 31 22070 32

89 INDRAVATI GRIDCO 3855 6 4527 7 3876 6 4918 7

Sl.No

MONSOON OFF PEAK WINTER PEAKMONSOON PEAK WINTER OFF PEAK

EASTERN REGION

STATION NAME


ANNEXURE 5



90 INDRAVATI PG 3902 6 4582 7 3924 6 4974 7

91 JAMSHEDPUR 11432 17 11431 16 11544 17 11653 17

92 JEERAT 9246 13 9422 14 9169 13 9463 14

93 JEYPORE 3992 6 4785 7 4014 6 5177 7

94 JINDAL 9116 13 9323 13 9342 13 7679 11

95 KAHALGAON 21255 31 21347 31 21868 32 22381 32

96 KODERMA -- -- -- -- 7359 11 7451 11

97 KOLAGHAT 10629 15 11121 16 10562 15 11084 16

98 MAITHON 13543 20 13523 20 13320 19 13471 19

99 MALDA 14261 21 14430 21 13834 20 14216 21

100 MALBASE 7483 11 7492 11 5787 8 5992 9

101 MEJIA 6913 10 6884 10 6864 10 6897 10

102 MENDHASAL 7154 10 7267 10 7198 10 7367 11

103 MERAMUNDALI 13294 19 13775 20 13859 20 14955 22

104 MPL 8610 12 8585 12 6546 9 6587 10

105 MUZAFFARPUR 12864 19 13048 19 12084 17 12382 18

106 PARULIA 14645 21 15842 23 14547 21 15704 23

107 PATNA 8836 13 8938 13 8674 13 8844 13

108 PURNEA 12528 18 12653 18 10552 15 11015 16

109 PURULIA PS 6156 9 9177 13 6173 9 8392 12

110 PUSAULI_E 9602 14 9713 14 9721 14 9887 14

111 RANCHI 9833 14 9517 14 7841 11 7923 11

112 RENGALI 14850 21 15379 22 15787 23 16612 24

113 ROURKELA 15928 23 15915 23 17233 25 17398 25

114 SAGARDIGHI 10628 15 10820 16 10467 15 10738 15

115 STERLITE 10177 15 10172 15 10064 15 10039 14

116 SUBHAS GRAM 6116 9 6160 9 6090 9 6182 9

117 TALA 8563 12 8571 12 6247 9 6476 9

118 TALCHER STG 2 19014 27 19713 28 20833 30 22070 32

119 TISTA 4981 7 4983 7 3523 5 4822 7

120 BALIPARA 3460 5 3447 5 4617 7 3500 5

121 BONGAIGAON 5046 7 5049 7 5185 7 4887 7

122 MISA 3087 4 2850 4 3794 5 3144 5

123 RANGANADI 2400 3 2384 3 4083 6 2424 3

124 ALMATTY 7245 10 7433 11 6099 9 6173 9

125 ARASUR 4871 7 5134 7 4919 7 5185 7

126 BELLARY TPS 10373 15 10577 15 10553 15 10631 15

127 BHADRAWATI_S 4316 6 4304 6 4431 6 4435 6

128 BUPAL PALLY 8001 12 8079 12 7582 11 7634 11

129 CHITTOR 5956 9 6041 9 5776 8 5827 8

130 CUDDAPAH 8347 12 8581 12 8134 12 8266 12


WINTER OFF PEAK WINTER PEAK

Sl.No STATION NAME

MONSOON OFF PEAK MONSOON PEAK

SOUTHERN REGION


ANNEXURE 5



131 DICHPALLY 3453 5 3431 5 3475 5 3466 5

132 GAJWEL 6744 10 6799 10 6880 10 6936 10

133 GAZUWAKA EAST 1965 3 2945 4 1967 3 3072 4

134 GAZUWAKA SOUTH 11645 17 12536 18 12883 19 13114 19

135 GHANAPUR 13190 19 14064 20 14068 20 14831 21

136 GMR 11951 17 14026 20 15452 22 15807 23

137 GOOTY 12175 18 12816 18 11993 17 12374 18

138 GOTAMI 8625 12 9949 14 10631 15 10781 16

139 GUTTUR 9631 14 10504 15 10157 15 10456 15

140 GVK 11357 16 13167 19 14365 21 14670 21

141 HASSAN 3986 6 3994 6 5779 8 5789 8

142 HIRIYUR 7831 11 8177 12 7807 11 7848 11

143 HOODY 10576 15 11232 16 10307 15 10735 15

144 HOSUR 8730 13 9091 13 8477 12 8754 13

145 JINDAL 10587 15 10808 16 10865 16 10952 16

146 KAIGA 7106 10 8105 12 8168 12 8414 12

147 KALIVNTHAPATTU 7084 10 7274 10 6651 10 6758 10

148 KALPAKA 12001 17 12934 19 13306 19 13549 20

149 KARAIKUDI 5567 8 5873 8 5637 8 5924 9

150 KHAMMAM 14851 21 15717 23 14207 21 14696 21

151 KOLAR 10880 16 11590 17 10593 15 11078 16

152 KONASEEMA 9500 14 10946 16 12006 17 12202 18

153 KOTHAGUDEM TPS 10297 15 10551 15 8398 12 8509 12

154 KUDAMKULAM -- -- 46 6699 4514 7 4718 7

155 KURNOOL 8698 13 9131 13 8513 12 8921 13

156 LANCO 11901 17 12897 19 13722 20 14226 21

157 MADURAI 8071 12 8792 13 8025 12 8692 13

158 MAHBOOBNAGAR 6874 10 7176 10 6992 10 7030 10

159 MALKAPURAM 8402 12 8611 12 8593 12 8762 13

160 MAMIDIPALLY 11631 17 12559 18 11758 17 12649 18

161 MUNIRABAD 6571 9 6729 10 6584 10 6603 10

162 MYSORE 5619 8 5695 8 6418 9 6467 9

163 NARENDRA 6862 10 7479 11 7373 11 7559 11

164 NEELAMANGALA 11541 17 12497 18 11300 16 11941 17

165 NELLORE 5920 9 5954 9 5512 8 5526 8

166 NEYVELI 10629 15 12351 18 10598 15 12320 18

167 NEYVELI 2EX4 10055 15 11567 17 10034 14 11549 17

168 NEYVELI1 EX4 8778 13 10165 15 8782 13 10170 15

169 PONDCHERRY 6766 10 7120 10 6316 9 6674 10

170 PUGALURU 6702 10 7189 10 6700 10 7176 10

171 RAICHUR TPS 12940 19 13586 20 12589 18 12919 19

172 RAMAGUNDAM 17481 25 18274 26 23845 34 25233 36

173 SALEM 10392 15 11249 16 10206 15 11056 16

174 SIMHADRI 11870 17 12769 18 13127 19 13361 19

175 SIMHDRI 10948 16 11740 17 12030 17 12225 18


Sl.No STATION NAME



ANNEXURE 5



176 SOMANAHALLI 10634 15 11373 16 10392 15 10887 16

177 SRI PERUMUBUDUR 8716 13 9045 13 7945 11 8136 12

178 SRI SALEM 9561 14 11643 17 9191 13 11721 17

179 SVCHTRAM 6424 9 6548 9

180 TALAPALLY 12845 19 13676 20 13195 19 13727 20

181 TALGUPPA 3637 5 3737 5 3736 5 3757 5

182 TIRUNELVELLI 6122 9 6551 9 6175 9 6571 9

183 TRICHI 6910 10 7438 11 6949 10 7464 11

184 TRICHUR 5056 7 5397 8 5283 8 5561 8

185 TRIVANDRUM 3869 6 4092 6 4009 6 4210 6

186 UDUMALPET 8600 12 9557 14 8690 13 9510 14

187 VALLUR 6075 9 6155 9

188 VEMAGIRI 12200 18 14343 21 15840 23 16216 23

189 VIJAYWADA 13980 20 15481 22 16482 24 17256 25

190 VTS 13160 19 14473 21 15349 22 16107 23

191 WARANGAL 9815 14 9988 14 9659 14 9781 14

192 ANPARA C 6080 5 6074 5 6115 5 6193 5

193 ABDULLAPUR 13212 19 13541 20 13493 19 14713 21

194 AGRA (UP) 15072 22 15180 22 14938 22 15439 22

195 AGRA PG 18848 27 18979 27 18515 27 19297 28

196 ALLAHABAD 15501 22 15573 22 15409 22 15684 23

197 AMRITSAR 6976 10 7113 10 6096 9 6834 10

198 ANPARA 20654 30 20590 30 21039 30 21374 31

199 AURYA 13317 19 13375 19 13390 19 13694 20

200 AZAMGARH 12260 18 12407 18 12265 18 12509 18

201 BAGHLIHAR 6948 10 6961 10 4739 7 6127 9

202 BAHADURGARH 14182 20 14289 21 13514 20 14173 20

203 BALIA 765 Kv 13825 20 13987 20 13781 20 14085 20

204 BALLABHGARH 28766 42 28901 42 26973 39 28554 41

205 BAMNAULI 23696 34 23869 34 22322 32 23660 34

206 BARELI 14451 21 14516 21 13597 20 14280 21

207 BARELI-PG 15452 22 15521 22 14542 21 15272 22

208 BARMER 6752 10 6752 10 6407 9 6447 9

209 BASPA 7452 11 8196 12 8294 12 10786 16

210 BASSI 12931 19 12991 19 12743 18 13039 19

211 BAWANA 29473 43 29779 43 26966 39 29362 42

212 BHILWARA 4019 6 3998 6 3987 6 3987 6

213 BHINMAL 4641 7 4678 7 4631 7 4685 7

214 BHIWADI 14716 21 14803 21 14024 20 14574 21

215 BHIWANI 13279 19 13373 19 12674 18 13315 19

216 BIKANER 4297 6 4298 6 4311 6 4328 6

217 CHABRA 4785 7 4751 7 4462 6 4478 6

Sl.No STATION NAME

MONSOON OFF PEAK MONSOON PEAK WINTER OFF PEAK WINTER PEAK

NORTHERN REGION


ANNEXURE 5



218 CHAKAN 8783 13 9343 13 9212 13 9567 14

219 CHAMER-1 9447 14 9253 13 5262 8 8802 13

220 CHAMER-2 9189 13 8819 13 4744 7 7647 11

221 CHAMERA-POL 9088 13 8729 13 -- -- -- --

222 DADRI-HVDC 32652 47 32756 47 28876 42 30923 45

223 DADRI-NCR 33594 48 33704 49 29619 43 31763 46

224 DAULATABAD 5894 9 5904 9 7479 11 7626 11

225 DEHAR 6757 10 6900 10 4578 7 5432 8

226 DULHASTI 4332 6 4335 6 2575 4 3752 5

227 FATEHABAD 11923 17 11964 17 11331 16 11800 17

228 GORAKHPUR 12512 18 12700 18 12379 18 12666 18

229 GORAKPUR_UP 10068 15 10228 15 10065 15 10274 15

230 GREATER NOIDA 24617 36 24685 36 22772 33 23983 35

231 GURGAON 12842 19 12883 19 12677 18 13039 19

232 HERAPUR 11648 17 11691 17 11369 16 11583 17

233 HINDAUN 4026 6 4046 6 3112 4 3132 5

234 HISSAR 18880 27 19053 28 17567 25 18890 27

235 JALANDHAR 14194 20 14310 21 10347 15 13246 19

236 JHAJAR_N 7712 11 7873 11

237 JHAJJAR 11784 17 11825 17 11483 17 11831 17

238 JODHPUR 8909 13 8910 13 8827 13 8905 13

239 KAITHAL 12700 18 12807 18 12130 18 12891 19

240 KANKROLI 8397 12 8416 12 8353 12 8456 12

241 KANPUR 21935 32 21988 32 21580 31 22227 32

242KANPUR-BALLABGARH-FSC22386 3 2377 3 2458 4 2425 4

243KANPUR-BALLABGARH-FSC32386 3 2377 3 2458 4 2425 4

244 KARCHAM WANGTOO 8049 12 8976 13 9325 13 12490 18

245 KASHIPUR 5277 8 5290 8 5119 7 5266 8

246 KHEDAR 11671 17 11685 17 11142 16 11510 17

247 KIRORI 10972 16 10986 16 10509 15 10836 16

248 KISHENPUR 10721 15 10771 16 6568 9 9232 13

249 KOTA 7432 11 7409 11 6933 10 6986 10

250 KOTESHWAR 7676 11 7673 11 5659 8 8698 13

251 LUCKNOW_UP 13130 19 13243 19 12945 19 13281 19

252 LUCKNOW-PG 17289 25 17453 25 16902 24 17413 25

253 LUDHIANA 10823 16 11014 16 9682 14 10739 16

254 MAHARANI BAGH 17175 25 17205 25 16984 25 17574 25

255 MAINPURI 8144 12 8204 12 8218 12 8367 12

256 MALERKOTA 10955 16 11150 16 10196 15 11075 16

257 MANDOLA 31517 45 31733 46 27997 40 30701 44

258 MAU 13535 20 13692 20 13506 19 13799 20

259 MEERUT 20758 30 20763 30 17533 25 20277 29

260 MERTA 9907 14 9902 14 9648 14 9748 14

261 MOGA 15319 22 15469 22 12076 17 14495 21


Sl.No STATION NAME



ANNEXURE 5



262 MUNDKA 25434 37 25642 37 23747 34 25370 37

263 MURADABAD 10916 16 10963 16 10353 15 10790 16

264 MURADNAGAR 19412 28 19446 28 18070 26 19031 27

265 MUZAFFARNAGAR 14815 21 14679 21 13151 19 14149 20

266 NALLAGARH 9989 14 10392 15 10005 14 11465 17

267 NATHPA 8738 13 9628 14 10125 15 14098 20

268 OBRA 12790 18 12756 18 12328 18 12513 18

269 PANIPAT 11358 16 11388 16 10859 16 11281 16

270 PANKI 21278 31 21334 31 20943 30 21561 31

271 PATIALA 10729 15 10952 16 10340 15 11192 16

272 PUSAULI_N 9602 14 9713 14 9721 14 9887 14

273 RAJWEST 7438 11 7437 11 6961 10 7007 10

274 RAPS_C 6963 10 6951 10 6767 10 6825 10

275 RATANGAR 7477 11 7485 11 7576 11 7631 11

276 RIHAND-G 17333 25 17302 25 16806 24 16977 25

277 RIHAN-HV 17109 25 17079 25 16593 24 16761 24

278 RISHIKESH 5792 8 5795 8 5480 8 5717 8

279 ROORKEE 7370 11 7364 11 6890 10 7227 10

280 SARNATH 12930 19 13021 19 12957 19 13180 19

281 SHOLAPUR pg 3010 4 3076 4 3026 4 3094 4

282 SHUJALPR -- -- 7374 11

283 SHREE CEMENT 5060 7 5054 7 5720 8 5762 8

284 SINGRAULI 23074 33 23010 33 22087 32 22365 32

285 SONEP-PG 9528 14 9617 14 10861 16 11337 16

286 SULTANPUR 7706 11 7814 11 7734 11 7866 11

287 SURATGARH 8009 12 8008 12 8533 12 8592 12

288 TEHRI 8518 12 8510 12 5149 7 8488 12

289 TEHRI-POL 7813 11 7809 11 5729 8 8875 13

290 UNNAO 18841 27 18950 27 18348 26 18937 27

291 URI G-1 4909 7 4941 7 3177 5 3962 6

292 VERSANA 4523 7 4746 7 5515 8 5809 8

293 VINDHYCHA BT 21214 31 21160 31 20379 29 20630 30

294 VISHNU PRAYAG 3562 5 3306 5 2998 4 3048 4

295 WAGOORA 6150 9 6210 9 4160 6 5242 8


Sl.No STATION NAME



ANNEXURE 6

Surge Impedance Loading (SIL) of transmission lines.

NLDC, 2012 REACTIVE POWER MANAGEMENT-a resource handbook 1 of 1

ANNEXURE 7

LIST OF 765KV LINES TO BE COMMISSIONED DURING 2012

Sl.

NoREGION UTILITY NAME OF THE LINE

Ckt. Type

(Tower)

Line Length (in

km)TARGET DATE Remarks

1STATE SECTOR-

UPPCLAnpara D - Unnao S/C 416 Jan-12

2 Balia-Lucknow S/C 320 Feb-12

3 Meerut - Bhiwani line S/C 175 May-12

4 Agra - Jhatikara S/C 245 Jun-12

5 Jhatikara - Bhiwadi - Moga S/C 358 Jun-12

6 Meerut - Agra S/C 260 Jun-12

7 Fatehpur- Agra line-II S/C 303 Aug-12

8 Fatehpur- Agra Line I S/C 325 Aug-12

9 Rihand - Vindhyachal Pooling Station line-I S/C 32 Nov-12

10 Rihand - Vindhyachal Pooling Station line-II S/C 31 Nov-12

11 Anta - Phagi (Jaipur South Ckt-1) S/C 210 Nov-12

12 Anta - Phagi (Jaipur South Ckt-2) S/C 220 Nov-12

13 2nd S/C Seoni (PG)Wardha (PG) line (initially to be operated at 400kV) S/C 261 Feb-12

14 LILO of Sipat - Seoni line at WR Pooling station Near Sipat S/C 8 Feb-12

15 LILO of Sipat - Seoni (2nd Ckt) at WR Pooling station Near Sipat S/C 8 Feb-12

16 Bina - Indore S/C 311 Mar-12

17 Satna - Bina line -I S/C 274 Mar-12

18 Gwalior - Jaipur (RVPN) line S/C 300 Nov-12

19 Sasan - Vindhyachal Pooling Station line S/C 6 Nov-12

20 Satna - Gwalior line (359 Km + 60 Km D/C Portion) Ckt-II D/C + S/C 331 Nov-12

21 Satna - Gwalior line (Ckt-I) S/C 392 Nov-12

22 Vindhyachal Pooling Station - Satna line (234 Km + 12 Km D/C S/C Portion) Ckt-II D/C + S/C 234 Nov-12

23 Vindhyachal Pooling Station Satna line (Ckt-I) S/C 265 Nov-12

24 Sasan - Satna line -I S/C 246 Dec-12

25 Sasan - Satna line -II S/C 243 Dec-12

26 Satna - Bina line -II S/C 276 Dec-12

27 Gaya - Balia S/C 358 Feb-12

28 Sasaram - Fatehpur Line I S/C 320 Mar-12

29 Gaya-Sasaram S/C 145 Mar-12

30 Ranchi-WR Pooling Station S/C 398 Aug-12

31 Sasaram - Fatehpur line-II S/C 260 Dec-12

EASTERN

REGION

CENTRAL

SECTOR

NORTHERN

REGION

WESTERN

REGION

STATE SECTOR-

RAJASTHAN

(RVPNL)

CENTRAL

SECTOR

CENTRAL

SECTOR


ANNEXURE 8

Shunt capacitors installed capacity-All India level.

Sl.

No

Region

(A)

Total capacity in

MVARRemarks

1 Northern 27694

2 Western 19725

3 Southern 16109

4 Eastern *ER Data not

available

5 North Eastern 175

TOTAL 63703

LIST OF SHUNT CAPACITORS


ANNEXURE 9

SERIES COMPENSATION AND SVC –ALL INDIA LEVEL

SL.

NOREGION LINE COMPENSATION END REMARKS

1 Panki-Muradnagar 40% Muradnagar Agency is UPPCL

2 Unnao-Bareilley(UP) - 1 45% Unnao Agency is UPPCL

3 Unnao-Bareilley(UP) - 2 45% Unnao Agency is UPPCL

4 Kanpur-Ballabhgarh 1 35% Ballabhgarh



7 Balia-Lucknow 1 40% Lucknow ( PG)

8 Balia-Lucknow 2 40% Lucknow ( PG)

9 Gorakhpur-Muzaffarpur 1 40% & 10-15%

(Dynamic)Gorakhpur FSC + TCSC

10 Gorakhpur-Muzaffarpur 2 40% & 10-15%

(Dynamic)Gorakhpur FSC + TCSC

11 Lucknow - Gorakhpur 1 30% Lucknow ( PG)




15 Allahabad-Mainpuri 1 40% Mainpuri

16 Allahabad-Mainpuri 2 40% Mainpuri

17 Mandola-Bareilley - 1 30% Bareilley ( PG)

18 Mandola-Bareilley - 2 30% Bareilley ( PG)

19 Kishenpur-Pampore 1 (220 kV) 40% Kishenpur Not in service

20 Kishenpur-Pampore 2 (220 kV) 40% Kishenpur Not in service

21 Khandwa-Seoni 1 40% Khandwa

22 Khandwa-Seoni 2 40% Khandwa

23 Adani-Sami 1 38% Sami Agency is Adani

24 Adani-Sami 2 38% Sami Agency is Adani

25 Raigarh-Raipur 1 40% fixed, +15%/-5%

dynamicRaipur FSC + TCSC

26 Raigarh-Raipur 2 40% fixed, +15%/-5%

dynamicRaipur FSC + TCSC

SERIES COMPENSATION & SVC –ALL INDIA LEVEL

NR

WR


ANNEXURE 9

SERIES COMPENSATION AND SVC –ALL INDIA LEVEL

SL.

NOREGION LINE COMPENSATION END REMARKS

27 Purnea-Muzaffarpur 1 40% fixed, +15%/-5%

dynamicPurnea FSC + TCSC

28 Purnea-Muzaffarpur 2 40% fixed, +15%/-5%

dynamicPurnea FSC + TCSC

29 Ranchi-Sipat 1 40% Ranchi FSC of ckt.1 out since

04.5.09

30 Ranchi-Sipat 2 40% Ranchi FSC of ckt.1 out since

04.5.09

31 Rengali-Indravati 40% Rengali Not in service

32 Meramundali-Jeypore 40% Jeypore

33 Jeypore-Gazuwaka 1 40% Jeypore

34 Jeypore-Gazuwaka 2 40% Jeypore

35 N'Sagar-Cudappa 1 40% Cudappa

36 N'Sagar-Cudappa 2 40% Cudappa

37 Gooty-Hoody 40% Gooty

38 Gooty-Neelamangala 40% Gooty

SVC (Static Sar Compensator)

S.No. Location ID Rating MVAr Remarks

1 SVC-1 ±140

2 SVC-2 ±140

ER

SERIES COMPENSATION & SVC –ALL INDIA LEVEL

400kV

KANPUR

SR


ANNEXURE10

ICT TAP POSITION DETAILS

Note:

% age kV

1 ABDULLAPUR PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11



4 ALLHABAD PGCL-NR1 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

5 ALLHABAD PGCL-NR1 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 11

6 AMRITSAR PGCL-NR2 400/220/33 ICT 01 315 CGL 17 9 1.25 5 11

7 AMRITSAR PGCL-NR2 400/220/33 ICT 02 315 CGL 17 9 1.25 5 11

8 BAHADURGARH PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

9 BAHADURGARH PGCL-NR2 400/220/33 ICT 02 500 AREVA 17 9 1.25 5 11

10 BALLABGARH PGCL-NR1 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11




14 BASSI PGCL-NR1 400/220/33 ICT 01 315 TELK 17 9 1.25 5 13

15 BASSI PGCL-NR1 400/220/33 ICT 02 315 TELK 17 9 1.25 5 13

16 BAWANA PGCL-NR1 400/220/33 ICT 03 315 BHEL 17 9 1.25 5 11

17 BHINMAL PGCL-NR1 400/220/33 ICT 01 315 CGL 17 9 1.25 5 9

18 BHINMAL PGCL-NR1 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 9

19 BHIWADI PGCL-NR1 400/220/33 ICT 01 315 TELK 17 9 1.25 5 11

20 BHIWADI PGCL-NR1 400/220/33 ICT 02 315 TELK 17 9 1.25 5 11

21 FATEHABAD PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

22 FATEHABAD PGCL-NR2 400/220/33 ICT 02 315 CGL 17 9 1.25 5 11

23 GORAKHPUR PGCL-NR1 400/220/33 ICT 01 315 TELK 17 9 1.25 5 11

24 GORAKHPUR PGCL-NR1 400/220/33 ICT 02 315 CGL 17 9 1.25 5 11

25 GURGAON PGCL-NR1 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 9

26 HISAR PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

27 HISAR PGCL-NR2 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 11

28 HISAR PGCL-NR2 400/220/33 ICT 03 315 CGL 17 9 1.25 5 11

29 JALLANDHAR PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

30 JALLANDHAR PGCL-NR2 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 11

31 KAITHAL PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

32 KAITHAL PGCL-NR2 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 11

33 KANKROLI PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 9

34 KANKROLI PGCL-NR2 400/220/33 ICT 02 315 CGL 17 9 1.25 5 9

35 KANKROLI PGCL-NR2 400/220/33 ICT 03 315 BHEL 17 9 1.25 5 9

36 KANPUR PGCL-NR1 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 12

37 KANPUR PGCL-NR1 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 12

38 KISHENPUR PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 9

39 KISHENPUR PGCL-NR2 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 9

40 KOTA PGCL-NR2 400/220/33 ICT 01 315 CGL 17 9 1.25 5 9

41 KOTA PGCL-NR2 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 9

Sl

No.

STEPStation Name TT

TT-Total No. of Taps, NT-Nominal Tap, PT- Present Tap

NT PT

NORTHERN REGION

OwnerVoltage Ratio

(kV)Equpt.

Rating

(MVA)Make

NLDC-2012 REACTIVE POWER MANAGEMENT-a resource handbook 1 OF 10

ANNEXURE10


Note:

% age kV

42 LUCKNOW PGCL-NR1 400/220/33 ICT 01 315 CGL 17 9 1.25 5 9

43 LUDHIANA PGCL-NR2 400/132/33 ICT 01 315 BHEL 17 9 1.25 5 11

44 LUDHIANA PGCL-NR2 400/132/33 ICT 02 315 BHEL 17 9 1.25 5 11

45 LUDHIANA PGCL-NR2 400/132/33 ICT 03 315 ABB 17 9 1.25 5 11

46 MAHARANI BAGH PGCL-NR1 400/220/33 ICT 01 315 ABB 17 9 1.25 5 11

47 MAHARANI BAGH PGCL-NR1 400/220/33 ICT 02 315 ABB 17 9 1.25 5 11

48 MAHARANI BAGH PGCL-NR1 400/220/33 ICT 03 500 CGL 17 9 1.25 5 11

49 MAHARANI BAGH PGCL-NR1 400/220/33 ICT 04 500 CGL 17 9 1.25 5 11

50 MAINPURI PGCL-NR1 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 13

51 MAINPURI PGCL-NR1 400/220/33 ICT 02 315 CGL 17 9 1.25 5 13

52 MALERKOTLA PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

53 MALERKOTLA PGCL-NR2 400/220/33 ICT 02 315 CGL 17 9 1.25 5 11

54 MALERKOTLA PGCL-NR2 400/220/33 ICT 03 500 AREVA 17 9 1.25 5 11

55 MANDOLA PGCL-NR1 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 12

56 MANDOLA PGCL-NR1 400/220/33 ICT 02 315 CGL 17 9 1.25 5 12



59 MANDOLA(SPARE) PGCL-NR1 400/220/33 ICT 05 315 CGL 17 9 1.25 5 12

60 MEERUT PGCL-NR1 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11



63 MOGA PGCL-NR2 400/220/33 ICT 01 250 BHEL 17 9 1.25 5 14




67 MUZAFFARNAGAR PGCL-NR1 400/220/33 ICT 01 315 ALSTOM 17 9 1.25 5 9

68 NALLAGARH PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 10

69 NALLAGARH PGCL-NR2 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 10

70 PANIPAT(BB) PGCL-NR2 400/220/33 ICT 02 450 TELK 17 9 0.65 2.25 11

71 PATIALA PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

72 PATIALA PGCL-NR2 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 11

73 PATIALA PGCL-NR2 400/220/33 ICT 03 500 AREVA 17 9 1.25 5 11

74 ROORKEE PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 9

75 ROORKEE PGCL-NR2 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 9

76 SONEPAT PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

77 SONEPAT PGCL-NR2 400/220/33 ICT 02 315 ABB 17 9 1.25 5 11

78 WAGOORA PGCL-NR2 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 9



81 WAGOORA PGCL-NR2 400/220/33 ICT 04 315 ABB 17 9 1.25 5 9

82 AURIYA CCGPP NTPC 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 09

83 AURIYA CCGPP NTPC 400/220/33 ICT 02 315 TELK 17 9 1.25 5 09

84 DADRI TPS NTPC 400/220/33 ICT 01 500 CGL 17 9 1.25 5 11



EquipmentRating

(MVA)

NORTHERN REGION

OwnerVoltage Ratio

(kV)TT NT


MakeSTEP

PTSl

No.Station Name


ANNEXURE10


Note:

% age kV

87 DADRI GAS NTPC 400/220/33 ICT 04 500 CGL 17 9 1.25 5 11

88 DADRI GAS NTPC 400/220/33 ICT 05 500 BHEL 17 9 1.25 5 11

89 SINGRAULI STPS NTPC 400/132 ICT 01 100 BHEL 17 9 1.25 5 12

90 SINGRAULI STPS NTPC 400/132 ICT 02 100 BHEL 17 9 1.25 5 12

91 RIHAND STPS NTPC 400/132 ICT 01 200 PEEBLE UK 17 9 1.25 5 08

92 RIHAND STPS NTPC 400/132 ICT 02 200 BHEL 17 9 1.25 5 08

93 AGRA(UP) UPPTCL 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 10

94 AGRA(UP) UPPTCL 400/220/33 ICT 02 315 ALSTOM 17 9 1.25 5 10

95 AGRA(UP) UPPTCL 400/220/33 ICT 03 315 SIEMENS 17 9 1.25 5 10

96 AZAMGARH UPPTCL 400/220/33 ICT 01 315 BHEL 17 9 1.25 2.75 12

97 AZAMGARH UPPTCL 400/220/33 ICT 02 240 HITACHI 17 9 1.25 2.75 12

98 BAREILY(UP) UPPTCL 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

99 BAREILY(UP) UPPTCL 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 11

100 GRETER NOIDA UPPTCL 400/220/33 ICT 01 315 EMCO 17 9 1.25 5 9

101 GRETER NOIDA UPPTCL 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 9

102 GRETER NOIDA UPPTCL 400/220/33 ICT 03 315 TELK 17 9 1.25 5 9

103 GORAKHPUR(UP) UPPTCL 400/220/33 ICT 01 240 TELK 17 9 1.25 5 11

104 LUCKNOW(UP) UPPTCL 400/220/33 ICT 01 240 ALSTOM 17 9 1.25 5 10

105 LUCKNOW(UP) UPPTCL 400/220/33 ICT 02 240 HITACHI 17 9 1.25 5 10

106 MORADABAD UPPTCL 400/220/33 ICT 01 240 MITSUBISHI 17 9 1.25 5 09

107 MORADABAD UPPTCL 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 09

108 MURADNAGAR UPPTCL 400/220/33 ICT 01 240 BHEL 17 9 1.25 5 10



111 MUZAFFARNAGAR UPPTCL 400/220/33 ICT 02 315 ALSTOM 17 9 1.25 5 9

112 MUZAFFARNAGAR UPPTCL 400/220/33 ICT 03 315 TELK 17 9 1.25 5 9

113 OBRA-B TPS UPPTCL 400/220/33 ICT 01 240 ALSTHOM 17 9 1.25 5 13

114 OBRA-B TPS UPPTCL 400/220/33 ICT 02 240 ALSTHOM 17 9 1.25 5 13

115 PANKI 400 UPPTCL 400/220/33 ICT 01 240 BHEL 17 9 1.25 5 13

116 PANKI 400 UPPTCL 400/220/33 ICT 02 240 BHEL 17 9 1.25 5 13

117 SARNATH UPPTCL 400/220/33 ICT 01 240 BHEL 17 9 1.25 5 10

118 SARNATH UPPTCL 400/220/33 ICT 02 315 TELK 17 9 1.25 5 10

119 SULTANPUR UPPTCL 400/220/33 ICT 01 240 BHEL 17 5 1.25 2.75 11

120 SULTANPUR UPPTCL 400/220/33 ICT 02 240 HITACHI 17 5 1.25 2.75 11

121 UNNAO UPPTCL 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

122 UNNAO UPPTCL 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 11

123 ANPARA TPS UPUN 400/132 ICT 01 100 BHEL 17 9 1.25 5 1

124 ANPARA TPS UPUN 400/132 ICT 02 100 CGL 17 9 1.25 5 5

125 ANPARA TPS UPUN 400/132 ICT 03 100 CGL 17 9 1.25 5 9

126 MAU (KASARA)-400 UPPTCL 400/132 ICT 01 200 ABB 17 9 1.25 5 10

127 MAU (KASARA)-400 UPPTCL 400/132 ICT 02 200 ABB 17 9 1.25 5 11

128 BARMER RRVPNL 400/220/33 ICT 01 315 TELK 17 9 1.25 5 9

129 BHILWARA RRVPNL 400/220/33 ICT 01 315 AREVA 17 9 1.25 5 9

130 BIKANER RRVPNL 400/220/33 ICT 01 315 AREVA 17 9 1.25 5 9


TT NT PT

NORTHERN REGION

Sl

No.Station Name Owner

Voltage Ratio

(kV)Equipment

Rating

(MVA)

STEPMake


ANNEXURE10


Note:

% age kV

131 CHHABRA RRVPNL 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 9

132 HEERAPURA RRVPNL 400/220/33 ICT 01 250 TELK 17 9 1.25 5 09




136 HINDAUN RRVPNL 400/220/33 ICT 01 315 TELK 17 9 1.25 5 9

137 HINDAUN RRVPNL 400/220/33 ICT 02 315 CGL 17 9 1.25 5 9

138 JODHPUR RRVPNL 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 09

139 JODHPUR RRVPNL 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 09

140 MERTA RRVPNL 400/220/33 ICT 01 315 ALSTOM 17 9 1.25 5 11

141 RAJWEST RRVPNL 400/220/33 ICT 01 315 ABB 17 9 1.25 5 9

142 RATANGARH RRVPNL 400/220/33 ICT 01 315 TELK 17 9 1.25 5 10



145 SURATGARH TPS RVUN 400/220/33 ICT 01 315 CGL 17 9 1.25 5 12

146 SURATGARH TPS RVUN 400/220/33 ICT 02 315 CGL 17 9 1.25 5 12

147 BAMNAULI DTL 400/220/33 ICT 01 315 EMCO 17 9 1.25 5 9

148 BAMNAULI DTL 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 9

149 BAMNAULI DTL 400/220/33 ICT 03 315 BHEL 17 9 1.25 5 9

150 BAMNAULI DTL 400/220/33 ICT 04 315 TELK 17 9 1.25 5 9

151 BAWANA DTL 400/220/33 ICT 01 315 BHEL 17 9 1.25 5 11

152 BAWANA DTL 400/220/33 ICT 02 315 BHEL 17 9 1.25 5 11

153 BAWANA DTL 400/220/33 ICT 04 315 TELK 17 9 1.25 5 11

154 MUNDKA DTL 400/220/33 ICT 01 315 TELK 17 9 1.25 5 9

155 MUNDKA DTL 400/220/33 ICT 02 315 EMCO 17 9 1.25 5 9

156 KASHIPUR PTCUL 400/220/33 ICT 01 315 ABB 17 9 1.25 5 12

157 KASHIPUR PTCUL 400/220/33 ICT 02 315 ABB 17 9 1.25 5 12

158 RISHIKESH 400 PTCUL 400/220/33 ICT 01 240 BHEL 17 9 1.25 5 9

159 RISHIKESH 400 PTCUL 400/220/33 ICT 02 240 MITSUBISHI 17 9 1.25 5 9

160 BHIWANI(BB) BBMB 400/220/33 ICT 01 500 TELK 17 9 1.25 5 10

161 DEHAR HEP BBMB 400/220/33 ICT 01 250 TELK 9 5 1.25 5 02

162 PANIPAT(BB) BBMB 400/220/33 ICT 01 450 TELK 17 9 0.65 2.25 11

NORTHERN REGION


EquipmentRating

(MVA)Make TT NT

Sl

No.Station Name Owner

Voltage Ratio

(kV)

STEPPT


ANNEXURE 10


% age kV

1 Raigarh 2x315 17 9 1.25 5 11

2 Jabalpur 2x315 17 9 1.25 5 9B

3 Satna 2x315 17 9 1.25 5 9B

4 Raipur 3x315 17 9 1.25 5 11

5 Mapusa 2x315 17 9 1.25 5 10

6 Vapi 2x315 17 9 1.25 5 12

7 Boisar 2x315 17 9 1.25 5 9

8 Khandwa 2x315 17 9 1.25 5 11

9 Seoni (765/400KV) 3x1500 23 9 1.25 5 9B

10 Seoni 2x315 17 9 1.25 5 9B

11 Bhatapara 2x315 17 9 1.25 5 9B

12 Rajgarh 2x315 17 9 1.25 5 11

13 Gwalior 2x315 17 9 1.25 5 9B

14 Damoh 2x315 17 9 1.25 5 9B

15 Itarasi 1x315 17 9 1.25 5 11

16 Dehgam 2x315 17 9 1.25 5 12

17 Wardha 2x315 17 9 1.25 5 11

18 Bina 1x315 17 9 1.25 5 9

19 Solapur 2x315 17 9 1.25 5 9

20 Pune 2x315 17 9 1.25 5 9

21 ASOJ 2x500 17 9 1.25 5 12

22 WANAKBORI 1x500 17 9 1.25 5 9

23 SOJA(Nardipur) 2x500 17 9 1.25 5 11

24 Jetpur 3x315 17 9 1.25 5 9

25 Chorania (Limdi) 2x500 17 9 1.25 5 13

26 Hadala(Rajkot) 2X315 17 9 1.25 5 9

27 GPEC 1x500 17 9 1.25 5 11

28 Kasor 1x500 17 9 1.25 5 9B

29 Amreli 2x315 17 9 1.25 5 12

30 Kansari(Zerda) 3x315 17 9 1.25 5 12

31 APL, Mundra 2x315 17 9 1.25 5 7

32 Ranchodpura(VADAVI) 2x315 17 9 1.25 5 9B

33 Korba (W) 1x500 17 9 1.25 5 12

34 Bhilai 3x315 17 9 1.25 5 13,13,9

35 Satpura 1x500 17 9 1.25 5 10

36 Indore 4x315 17 9 1.25 5 13,13,9B,9

37 Bhopal 3x315 17 9 1.25 5 9

38 Nagda 3x315 17 9 1.25 5 11

39 Birsinghpur 1x500 17 9 1.25 5 11

40 Katni 1x315 17 9 1.25 5 7

41 Bina 3x315 17 9 1.25 5 9

TT NT

STEP

Sl.No Substation

CHATTISGARH

WESTERN REGION


MADHYA PRADESH

Trafo. Cap PT Remarks

POWERGRID

GUJARAT


ANNEXURE 10


% age kV

42 Kalwa 1x600+2x500 17 9 1.25 5 11

43 Bhusawal 2x200 17 9 1.25 5 12

44 Bhusawal 1x315+1x500 17 9 1.25 5 11

45 Jejuri 2x500 17 9 1.25 5 9

46 Solapur 2x500 17 9 1.25 5 11

47 Koradi 1x300+1X315 17 9 1.25 5 11

48 Nagothane 2X315+1x500 17 9 1.25 5 9B

49 Chandrapur 2x315 17 9 1.25 5 12

50 Parli 2x315 17 9 1.25 5 12

51 Karad 3X315 17 9 1.25 5 9

52 Lonikhand 3x315 17 9 1.25 5 13

53 Aurangabad 2x315+1x500 17 9 1.25 5 9

54 Padghe 3x315 17 9 1.25 5 8

55 New Koyna 2x315 17 9 1.25 5 11

56 Dhule 2x315 17 9 1.25 5 11

57 Bableshwar 2x315+1x500 17 9 1.25 5 11,11,9

58 Kolhapur 4x315 17 9 1.25 5 9

59 Akola 1x315 17 9 1.25 5 8

60 Kharghar 2x315 17 9 1.25 5 11

61 Chakan 2x315 17 9 1.25 5 11

62 Seoni (765/400KV) 2x1000 23 9 1.25 5 7

63 VINDHYACHAL 3x200 17 9 1.25 5 9B

64 GANDHAR 2X500 17 9 1.25 5 10

65 Sardar Sarovar 2x315 17 9 1.25 5 9

66 JPL, Tamnar 2x315 17 9 1.25 5 9B

67 NSPCL,Bhilai 2x315 17 9 1.25 5 8

`

CENTRAL SECTOR/SSP/IPP

WESTERN REGION


Sl.No

MAHARASHTRA

RemarksSubstation Trafo. Cap TT NT

STEP

PT


ANNEXURE 10


Note:

% age kV

1 CUDDAPAH - 1 400/220 315 BHEL 17 9 1.25 5 9

2 CUDDAPAH - 2 400/220 315 BHEL 17 9 1.25 5 9

3 GAJUWAKA - 1 400/220 315 CGL 17 9 1.25 5 11

4 GAJUWAKA - 2 400/220 315 CGL 17 9 1.25 5 11

5 GOOTY - 1 400/220 315 CGL 17 9 1.25 5 12

6 GOOTY - 2 400/220 315 BHEL 17 9 1.25 5 12

7 HYDERABAD -1 400/220 315 CGL 17 9 1.25 5 9

8 HYDERABAD - 2 400/220 315 CGL 17 9 1.25 5 9

9 HYDERABAD - 3 400/220 315 CGL 17 9 1.25 5 9

10 KHAMMAM - 1 400/220 315 CGL 17 9 1.25 5 12

11 KHAMMAM - 2 400/220 315 BHEL 17 9 1.25 5 12

12 MUNIRABAD - 1 400/220 315 TELK 17 9 1.25 5 9

13 MUNIRABAD - 2 400/220 315 BHEL 17 9 1.25 5 9

14 NAGARJUNSAGAR - 1 400/220 315 TELK 17 9 1.25 5 10

15 NAGARJUNSAGAR - 2 400/220 315 TELK 17 9 1.25 5 10

16 NAGARJUNSAGAR - 3 400/220 315 BHEL 17 9 1.25 5 10

17 VIJAYAWADA - 1 400/220 315 CGL 17 9 1.25 5 14

18 VIJAYAWADA - 2 400/220 315 CGL 17 9 1.25 5 14

19 WARRANGAL - 1 400/220 315 TELK 17 9 1.25 5 9

20 WARRANGAL - 2 400/220 315 TELK 17 9 1.25 5 9

1 ARASUR - 1 400/220 315 BHEL 17 9 1.25 5 9

2 ARASUR - 2 400/220 315 BHEL 17 9 1.25 5 9

3 BANGALORE - 1 400/220 501 BHEL 17 9 1.25 5 8

4 BANGALORE - 2 400/220 501 CGL 17 9 1.25 5 8

5 HASSAN - 1 400/220 315 CGL 17 9 1.25 5 9

6 HASSAN - 2 400/220 315 CGL 17 9 1.25 5 9

7 HIRIYUR - 1 400/220 315 BHEL 17 9 1.25 5 9

8 HIRIYUR - 2 400/220 315 BHEL 17 9 1.25 5 9

9 HOSUR - 1 400/230 315 CGL 17 9 1.25 5 10

10 HOSUR - 2 400/230 315 CGL 17 9 1.25 5 10

11 KALIVANDAPATTU - 1 400/220 315 BHEL 17 9 1.25 5 7

12 KALIVANDAPATTU - 2 400/220 315 BHEL 17 9 1.25 5 7

13 KARAIKUDI - 1 400/230 315 CGL 17 9 1.25 5 9

14 KARAIKUDI -2 400/230 315 CGL 17 9 1.25 5 9

15 KOLAR - 1 400/220 501 CGL 17 9 1.25 5 7

16 KOLAR - 2 400/220 501 BHEL 17 9 1.25 5 7

17 MADURAI - 1 400/230 315 CGL 17 9 1.25 5 11

18 MADURAI - 2 400/230 315 CGL 17 9 1.25 5 11

19 MYSORE - 1 400/220 315 CGL 17 9 1.25 5 9

20 MYSORE - 2 400/220 315 CGL 17 9 1.25 5 9

TTStation NameVoltage Ratio

(kV)

Rating

(MVA)Make


NT PT

SOUTHERN REGION

POWERGRID SRTS - I

POWERGRID SRTS - 2

Sl No.STEP


ANNEXURE 10


Note:

% age kV

21 NARENDRA - 1 400/220 315 BHEL 17 9 1.25 5 9B

22 NARENDRA - 2 400/220 315 BHEL 17 9 1.25 5 9B

23 PUDUCHERY - 1 400/230 315 TELK 17 9 1.25 5 9

24 PUDUCHERY - 2 400/230 315 TELK 17 9 1.25 5 9

25 PUGALUR 400/230 315 AREVA 17 9 1.25 5 9

26 PUGALUR 400/230 315 AREVA 17 9 1.25 5 9

27 THIRUNELVELI - 1 400/220 315 TELK 17 9 1.25 5 9

28 THIRUNELVELI - 2 400/220 315 TELK 17 9 1.25 5 9

29 TRICHY - 1 400/230 315 TELK 17 9 1.25 5 9

30 TRICHY - 2 400/230 315 TELK 17 9 1.25 5 9

31 TRIVANDRUM - 1 400/220 315 BHEL 17 9 1.25 5 9

32 TRIVANDRUM - 2 400/220 315 BHEL 17 9 1.25 5 9

33 TRIVANDRUM - 3 400/220 315 BHEL 17 9 1.25 5 9

34 UDUMALPET - 1 400/230 315 BHEL 17 9 1.25 5 8

35 UDUMALPET - 2 400/230 315 BHEL 17 9 1.25 5 8

36 UDUMALPET - 3 400/230 315 AREVA 17 9 1.25 5 8

1 RAMAGUNDAM - 1 400/132 200 BHEL 17 9 1.25 5 12

2 RAMAGUNDAM - 2 400/132 200 BHEL 17 9 1.25 5 12

3 RAMAGUNDAM - 3 400/220 250 BHEL 17 9 1.25 5 12

4 RAMAGUNDAM - 4 400/220 250 BHEL 17 9 1.25 5 12

5 RAMAGUNDAM - 5 400/220 315 BHEL 17 9 1.25 5 12

1 NEYVELI II - 1 400/230 250 BHEL 17 9 1.25 5 10

2 NEYVELI II - 2 400/230 250 BHEL 17 9 1.25 5 10

1 KAIGA - 1 400/220 501 BHEL 17 9 1.25 5 11

2 KAIGA - 2 400/220 501 BHEL 17 9 1.25 5 11

Voltage Ratio

(kV)

SOUTHERN REGION

NTPC

NPCIL

NLC


Sl No.STEP

PTStation NameRating

(MVA)Make TT NT


ANNEXURE 10


Note:

% age kV

1 JEYPORE 400/220 P0WERGRID 2x315 17 9 1.25 5 16

2 JAMSHEDPUR 400/220 P0WERGRID 2x315 17 9 1.25 5 15

3 BIHARSHARIFF 400/220 P0WERGRID 3x315 17 9 1.25 5 12

4 BIDHANNAGAR 400/220 WBSETCL 2x315 17 9 1.25 5 14

5 MAITHON 400/220 P0WERGRID 2x315 17 9 1.25 5 13

6 ARAMBAGH 400/220 WBSETCL 3x315 17 9 1.25 5 13

7 JEERAT 400/220 WBSETCL 3x315 17 9 1.25 5 13

8 TALCHER 400/220 NTPC 2x315 17 9 1.25 5 13

9 MALDA 400/220 P0WERGRID 2x315 17 9 1.25 5 12

10 KOLAGHAT 400/220 WBSETCL 2x315 17 9 1.25 5 12

11 RENGALI 400/220 P0WERGRID 2x315 17 9 1.25 5 12

12 NEW PURNEA 400/220 P0WERGRID 2x315 17 9 1.25 5 11

13 SASARAM 400/220 P0WERGRID 2x315 17 9 1.25 5 11

14 PATNA 400/220 P0WERGRID 2x315 17 9 1.25 5 11

15 FARAKKA 400/220 NTPC 2x315 17 9 1.25 5 11

16 PARULIA 400/220 P0WERGRID 2x315 17 9 1.25 5 11

17 BAKRESHWAR 400/220 WBSETCL 2x315 17 9 1.25 5 11

18 SUBHASGRAM 400/220 P0WERGRID 2x315 17 9 1.25 5 11

19 BINAGURI 400/220 P0WERGRID 2x315 17 9 1.25 5 10

20 ROURKELA 400/220 P0WERGRID 2x315 17 9 1.25 5 10

21 MERAMUNDALI 400/220 OPTCL 2x315 17 9 1.25 5 10

22 BARIPADA 400/220 P0WERGRID 2x315 17 9 1.25 5 9

23 MENDASAL 400/220 OPTCL 2x315 17 9 1.25 5 9

24 MUZAFFARPUR 400/220 P0WERGRID 2x315 17 9 1.25 5 9B

25 RANCHI 400/220 P0WERGRID 2x315 17 9 1.25 5 9B

26 INDRAVATI 400/220 OPTCL 2x315 17 9 1.25 5 9B

POWERGRID ERTS - I

MakeRating

(MVA)

Voltage Ratio

(kV)Station Name

EASTERN REGION


Owner NTTTSl No.STEP

PT


ANNEXURE 10


Note:

% age kV

1BONGAIGAON

400/220P0WERGRID 1x315

TELK 17 9 1.25 512

2BALIPARA


TELK 17 9 1.25 510

3MISA


TELK 17 9 1.25 55

POWERGRID NERTS

OwnerRating

(MVA)Make TT



Sl No. Station NameVoltage Ratio

(kV)NT

STEPPT


ANNEXURE 11

Typical Transformer Tap Changer online/offline detail

Type1 On Load Tap Changer

Used in 400/220 kV, 3 Phase, 315 MVA, BHEL Make, ICT

Tap Position Tap Remarka

Numbar +/-5% % kV Location:

1 440 220 1.25 5 Maximum Turns Ratio Position

2 435 220 1.25 5

3 430 220 1.25 5

4 425 220 1.25 5

5 420 220 1.25 5

6 415 220 1.25 5

7 410 220 1.25 5

8 405 220 1.25 5

9 400 220 1.25 5 Nominal Tap

10 395 220 1.25 5

11 390 220 1.25 5

12 385 220 1.25 5

13 380 220 1.25 5

14 375 220 1.25 5

15 370 220 1.25 5

16 365 220 1.25 5

17 360 220 1.25 5 Minimum Turns Ratio Position

Type2 On Load Tap Changer

Used in 400/220 kV, 3 Phase, 450 MVA, Hitachi Make, ICT


Numbar +15 %,-5 % % kV Location:Panipat(BBMB)

1 400 253 1.25 2.75 Maximum Turns Ratio Position

2 400 250.5 1.25 2.75

3 400 247.5 1.25 2.75

4 400 244.75 1.25 2.75

5 400 242 1.25 2.75

6 400 239.25 1.25 2.75

7 400 236.15 1.25 2.75

8 400 233.75 1.25 2.75

9 400 231 1.25 2.75

10 400 228.25 1.25 2.75

11 400 225.5 1.25 2.75

12 400 222.75 1.25 2.75

13 400 220 1.25 2.75 Nominal Tap

14 400 217.25 1.25 2.75

15 400 214.5 1.25 2.75

16 400 211.75 1.25 2.75

17 400 209 1.25 2.75 Minimum Turns Ratio Position

Type3 Off Load Tap Changer

Used in 11/240 kV,3 Phase,Generator Transformer


Numbar +/- 10 % % kV Location:Kota

1 264 11 2.5 6 Maximum Turns Ratio Position

2 258 11 2.5 6

3 252 11 2.5 6

4 246 11 2.5 6

5 240 11 2.5 6 Nominal Tap

6 234 11 2.5 6

7 228 11 2.5 6

8 222 11 2.5 6

9 216 11 2.5 6 Minimum Turns Ratio Position


Used in 21/235 kV,3 Phase,Generator Transformer


Numbar +/- 10 % % kV Location:RAPSB

1 258.5 21 2.5 5.875 Maximum Turns Ratio Position

2 252.625 21 2.5 5.875

3 246.75 21 2.5 5.875

4 240.875 21 2.5 5.875

5 235 21 2.5 5.875 Nominal Tap

6 229.125 21 2.5 5.875

7 223.25 21 2.5 5.875

8 217.375 21 2.5 5.875

9 211.5 21 2.5 5.875 Minimum Turns Ratio Position

High

Voltage(kV)

Intermediate

Voltage (kV)

Step

Hig

h V

olt

ag

e S

ide

Step

Step

StepHigh

Voltage(kV)

Intermediate

Voltage (kV)

High

Voltage(kV)

Intermediate

Voltage (kV)

Hig

h V

olt

ag

e S

ide

Lo

w V

olt

ag

e S

ide

Hig

h V

olt

ag

e S

ide

Intermediate

Voltage (kV)

High

Voltage(kV)


ANNEXURE 11

Typical Transformer Tap Changer online/offline detail


Used in 11/220 kV, 1 Phase, 25 MVA, Crompton Greaves Make,Generator Transformer


Numbar +7.5/-2.5 % % kV Location:Tanakpur,Bairasiul

1 236.5/

√

3 11/

√

3 2.5 5.5 Maximum Turns Ratio Position

2 231/

√

3 11/

√

3 2.5 5.5

3 225.5/

√

3 11/

√

3 2.5 5.5

4 220/

√

3 11/

√

3 2.5 5.5 Nominal Tap

5 214.5/

√

3 11/

√

3 2.5 5.5 Minimum Turns Ratio Position


Used in 15.75/420 kV, 306 MVA,3 Phase,Generator Transformer


Numbar +2.5/-7.5 % kV Location:Tehri

1 430 15.75 2.5 10.5 Maximum Turns Ratio Position

2 419.5 15.75 2.5 10.5 Nominal Tap

3 409 15.75 2.5 10.5

4 398.5 15.75 2.5 10.5

5 388 15.75 2.5 10.5 Minimum Turns Ratio Position


Used in 1 Phase,Generator Transformer


Numbar +/-5% % kV Location:Dulhasti, Uri,Chamera-I

1 420/

√

3 11/

√

3 2.5 10 Maximum Turns Ratio Position

2 410/

√

3 11/

√

3 2.5 10

3 400/

√

3 11/

√

3 2.5 10 Nominal Tap

4 390/

√

3 11/

√

3 2.5 10

5 380/

√

3 11/

√

3 2.5 10 Minimum Turns Ratio PositionHig

h V

olt

ag

e

Sid

e

High

Voltage(kV)

Hig

h V

olt

ag

e

Sid

e

Intermediate

Voltage (kV)

Step

High

Voltage(kV)

Step

Hig

h V

olt

ag

e

Sid

e

Step

Intermediate

Voltage (kV)

Intermediate

Voltage (kV)

High

Voltage(kV)


ANNEXURE 12

SYNCHRONOUS CONDENSER AT ALL INDIA LEVEL

SL.

NOREGION SUBSTATION UTILITY RATING MVAR INSTALLED ON MAKE

1 Heerapura 220 kV RVPNL 20 33KV BUS SIEMENS

2 Heerapura 220 kV RVPNL 20 33KV BUS SIEMENS

SL.

NOREGION STATION UTILITY RATING MW

1 Pong BBMB 6 X 66 = 396

2 Larji HPSEB 3 X 42 = 126

3 Ranjit Sagar HEP (RSD) PSEB 4 X 150 = 600

4 Rana Pratap Sagar (RPS) RVUN 4 X 43 = 172

5 Jawahar Sagar (JS) RVUN 3 X 33 = 99

6 Tehri THDC 2 X 250 = 500

7 RBPH NCA 6X200=1200

8 KOYNA IV MSEGCL 4X250=1000

9 GHATGHAR MSEGCL 2X125=250

10 Sagar Andhra Pradesh 7 X 100.8 = 705.6

11 Sagar Andhra Pradesh 1 X 110 = 110

12 Srisailam LB Andhra Pradesh 6 X 150 = 900

13 Varahi Karnataka 2 X 115 = 230

14 Idukki Kerala 3 X 130 = 390

15 Kuttiadi Kerala 3 X 25 = 75

16 Lower Periyar Kerala 3 X 60 = 180

17 Basin Bridge Tamil Nadu 4 X 30 =120

18 Aliyar Tamil Nadu 1 X 60 = 60

7113.6TOTAL

WR

NR

LIST OF SYNCHRONOUS CONDENSER

NR

HYDRO STATIONS HAVING SYNCHRONOUS CONDENSER FACILITY

SR


Reactive Power Mangament-A Resource Handbook- Jan 2012 .Pdfxhrb0978575529b486abca7eb68e0e44469xhr

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