FGM IN SR

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Presentation on

FREE GOVERNOR MODE OPERATION

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FREE GOVERNOR OPERATION

WHYFREQ COMPARISION

MAY-02 & MAY-03

GOVERNOR

BEFORE GOVERNOR GOVERNOR RESPONSEIN NER

DEAD BAND GOVERNOR TIME LAG

BLOCKED GOVERNOR

ROLE

DROOPFREQUENCY DECAY RATEBACKLASH

TYPES OF CONTROLS

DROOP RESPONSE IN SR

ABT & GOVERNOR

ADVANTAGES

GOVERNOR TYPES

TIME DELAY

CHARACTERISTICS

PROBLEMS UCPE/NERC LIST OF GENERATORS

FREQUENCY BASED

DISPATCH

FREQUENCY BASED

DISPATCHSUPPRESSED GOVERNOR

ACTION

PID CONTROLPTI TAPE ORDERS

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ORDERS

IEGC 6.2 (e) & 6.2(f)IEGC 1.6IEGC 6.2 (g)

IEGC 6.2 (h)CERC ORDER ON

WB dt 02/01/01

KERALA LETTER

ON FGM

FREE GOVERNOR

OPERATION

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ROLE OF SYSTEM OPERATOR

LOAD GENERATION

BALANCE50

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WHY DOES FREQUENCY DROP ?

Sudden addition of load causes a drop in frequency.

An increased load is supplied through an increase in the load angle by which

the rotor lags the stator field.

It means a loss of Kinetic Energy of the rotating M/c and a slower speed

of rotation i.e. a lower frequency.

f = (P/2) X (N/60)Where f = frequency of the system

P = no of poles of the M/c.

N = rpm of the M/c.

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Load dependent on frequency Free Governor Operation

Under Frequency Operation

PRIMARY CONTROLS

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PRIMARY CONTROL (UCPE)Primary control involves the action of

turbine speed governors in generating units,which will respond where the speed(frequency) deviates from the speed(frequency) set point as a result of an

imbalance between generation and demandin the synchronously interconnectednetwork as a whole. Technical solidarity

between members will involve thesimultaneous action of primary control on allgenerating units involved in system control.

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PRIMARY CONTROL (UCPE)The various assumptions, characteristics and parametersapplied to primary control are as follows:

The maximum instantaneous deviation P betweengeneration and demand to be corrected by primary controlis 2000 MW

For the whole system, with a peak load of the order of20000 MW and an off-peak load of the order of 12000 MW,

assuming 1% self-regulation of load, the quasi-steady-state frequency deviation must not exceed 180 mHz andthe instantaneous frequency must not fall below 49.2 Hz inresponse to a shortfall in generation capacity equal to orless than 2000 MW. The overall network power frequencycharacteristic for the system is set at 1000 MW/Hz

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FREQUENCY RESPONSE (NERC)

NERC

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ABT AND GOVERNOR

POST ABT FREQUENCY WITHIN 49 TO 50.5HZ

ACHIEVED BY STAGGERING OF LOADS

FLUCTUATION IN FREQUENCY INCREASED

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FREQUENCY COMPARISON FOR

47.50

48.00

48.50

49.00

49.50

50.00

50.50

51.00

51.50

00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23

04-MARCH 02 & 03

2003

2002

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HUMAN GOVERNOR OPERATION

SYSTEM~TGX

GOVERNOR

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GOVERNOR

SPEED GOVERNOR IS THE CONTROLLING MECHANISM WHICH

CONTROLS THE INPUT TO THE PRIME MOVER AUTOMATICALLY WHEN

THERE IS A CHANGE IN SYSTEM SPEED (FREQUENCY)

WHEN THERE IS A CHANGE IN SYSTEM FREQUENCY GOVERNOR

RESPONSE BY CAUSING VALVES/GATES TO OPEN/CLOSE TO

INCREASE/DECREASE THE INPUT TO THE PRIME MOVER

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MISCONCEPTION

Governors attempt to restore frequency to normal.

In reality, Governors attempt to restore load generation balance, using

frequency change as a signal.

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CHARACTERISTICS

1. Respond promptly to a small change inspeed.

2. Adjust the throttle valve with a minimum

of overshoot.3. Have sufficient power to overcome

friction losses and unbalance forces in

the throttle valve.4. Permit very little speed fluctuation under

constant load and steam conditions.

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TYPES OF GOVERNORS

Mechanical shaft

Direct acting orifice

Oil relay

Precision oil relayElectronic governor

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DEAD BAND

DEAD BAND OF THE SPEED GOVERNORING SYSTEM IS THE TOTAL

AMOUNT OF CHANGE IN STEADY STATE SPEED WITHIN WHICH THEREIS NO ACTION BY GOVERNOR.

Turbine rated outputMW

Dead band percent ofrated speed

IN 50HZ BASE

< 5MW 0.15 0.075HZ

5 to 30mw 0.10 0.050HZ

> 30mw 0.06 0.030HZ

IEC - 45

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DROOP CHARACTERISTICS

THE AMOUNT OF SPEED (OR FREQUENCY) CHANGE THAT IS NECESSARY

TO CAUSE THE MAIN PRIME MOVER CONTROL MECHANISM TO MOVEFROM FULLY CLOSED TO FULLY OPEN.

NORMAL RANGE - 3 TO 5%

THE MINIMUM RATE OF CHANGE OF SPEED SHOULD NOT BE LESS THAN

0.4 TIMES OF ITS DROOP.

THE MAXIMUM RATE OF CHANGE OF SPEED SHOULD NOT BE MORE

THAN 3 TIMES OF ITS DROOP.

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5% DROOP ON 200MW GENERATOR

0

40

80

120

160

200

49 49.5 50 50.5 51 51.5

FREQ IN HZ --->

GENERATIONIN

MW

--->

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PARTICIPATION OF 5% DROOP ON 200MW & 500MW GENERATORS

0

100

200

300

400

500

600

49 49.5 50 50.5 51 51.5

FREQ IN HZ --->

GENERATIONIN

MW

--->

100MW for 0.5HZ

Frequency

40MW for 0.5HZ

Frequency

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GOVERNOR DROOP 5% (500MW UNIT)

0

100

200

300

400

500

600

47 47.5 48 48.5 49 49.5 50 50.5 51 51.5 52 52.5 53

FREQ IN HZ --->

GENERATIONINM

W

---->

600

500

300

200

0

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GOVERNOR DROOP 5% (210MW UNIT)

0

50

100

150

200

250

47 47.5 48 48.5 49 49.5 50 50.5 51 51.5 52 52.5 53

FREQ IN HZ --->

GENERATIONINM

W

---->

250

210

125

85

0

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RESPONSE BY A 500 MW GENERATOR WITH DIFFRENT DROOP

0

375

125

0

200

500

400

300

100

500

250

0

50

100

150

200

250

300

350

400

450

500

48 48.5 49 49.5 50 50.5 51 51.5

HZ->

MW

->

5 % DROOP

4 % DROOP

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GOVERNOR TIME LAG

TIME TAKEN BY GOVERNOR TO JUST BEGIN CHANGING POWER OUTPUT

TO STABILISE FREQUENCY.

OR

TIME BETWEEN A CHANGE IN GENERATOR SPEED & CHANGE IN

TURBINE POWER.

TIME DELAY IN GOVERNOR OPERATION

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Dead band 0.25 sec

Valve opening 0.5 sec

Steam flow 4 seconds

During transient state Governor is of little help.

Effect is felt during steady state

TIME DELAY IN GOVERNOR OPERATION

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BLOCKED GOVERNOR

BYPASSING THE GOVERNING FEEDBACK MECHANISM TO MAINTAIN

FIXED GENERATOR OUTPUT.

DISADVANTAGES:-

SYSTEM INSTABILITY

RESTORATION OF SYSTEM FREQUENCY TO NORMAL TAKES MORETIME AFTER A DISTURBANCE.

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FREQUENCY DECAY RATE

Approximate Freq 5 X Lost Generation

Decay Rate = --------------------------------------

In Hz / sec Remaining Generation

Example:-

2200MW200MW

Generation Lost

Freq decay rate = (5 X 200) / 2000 = 0.5 Hz /second

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NEYVELI U-4 ON FGM ON 19/06/2003

160

170

180

190

200

210

220

11:00 11:15 11:30 11:45 12:00 12:15 12:30 12:45 13:00

TIME ->

MW->

49

49.2

49.4

49.6

49.8

50

50.2

50.4

HZ->

GENERATION

FREQUENCY

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DROOP CHARACTERISTICS OF NYL U4

170

175

180

185

190

195

200

205

210

49.6 49.7 49.8 49.9 50 50.1 50.2 50.3 50.4 50.5

FREQ CHANGE 49.7 - > 50.4 0.7Hz

GEN CHANGE 205 -> 177 35MW

CHANGE IN GEN 28 MW FOR 0.7 Hz CHANGE IN FREQ

FOR 200 MW CHANGE IN GEN FREQ CHANGE REQD =

(200*0.7)/28 = 5 Hzi.e 5*100 /50 = 10% Droop

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NLY U6 ON FGM ON 15/07/03

145

150

155

160

165

170

175

180

185

190

195

11:30 11:45 12:00 12:15 12:30

TIME-->

MW

-->

49

49.2

49.4

49.6

49.8

50

50.2

50.4

50.6

HZ-->

GENERATION

FREQUENCY

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DROOP CHARACTERISTICS OF NYL U6

160

165

170

175

180

185

190

195

49.8 49.9 50 50.1 50.2 50.3 50.4 50.5 50.6 50.7

FREQ CHANGE 49.9 - > 50.5 0.6Hz

GEN CHANGE 191 -> 168 23MW

CHANGE IN GEN 24 MW FOR 0.6 Hz CHANGE IN FREQ

FOR 200 MW CHANGE IN GEN FREQ CHANGE REQD =

(200*0.6)/24 = 5 Hzi.e 5*100 /50 = 10% Droop

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IDUKKI GENERATION ON 16/07/2003

0

50

100

150

200

250

300

350

400

0 2 4 6 8 10 12 14 16 18 20 22 0

MW

48.5

49

49.5

50

50.5

51

FREQ->

FREQUENCY

GENERATION

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DROOP CHARACTERSTICS OF IDUKKI

0

50

100

150

200

250

300

350

400

49.3 49.4 49.5 49.6 49.7 49.8 49.9 50 50.1

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49.849.1 49.749.649.549.449.2 49.3 49.9

POINT APOINT B

POINT C

POINT D

POINT A - GENERATION LOSS

POINT B GOVERNOR ACTION STARTED

POINT C - FREQUENCY AFTER GOVERNER ACTION

POINT D FREQUENCY AFTER OPERATOR ACTION

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The distance through which one part of connected machinery, as a

wheel, piston, or screw, can be moved without moving the connected parts.

BACKLASH

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BOILER CONTROLS

BOILER FOLLOWING SYSTEM

TURBINE FOLLOWING SYSTEM

INTEGRATED CONTROL SYSTEM

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50

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ADVANTAGES

1. Reduce the random change of frequency

2. Mitigate effect of load generation mismatch

3. Prevents wastage of fuel during low load condition

4. Faster restoration from grid disturbance

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PROBLEMS

1. Steam deposits on the valve stem .2. Lubrication deposits (i.e., soaps, dirt, detergents,

etc.) in the top works of the valve exposed to theelements.

3.Mechanical failures of the valve resulting from bentstems, either in the valve proper or the upperworks, damaged split couplings, etc., all withinabout a 6" area near the center of the valvemechanism.

4. Galling of the piston in the hydraulic latch cylinder.5. Jamming of the screw spindle in the larger

cylinder-type valve design due to forcing byoperations personnel

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FREE GOVERNOR OPERATION

Mother of all ControlsSelf healing mechanism

Collectively ControlMost equitable

Reduces risk of collapseMakes restoration easy

World wide mandatory practice

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5% DROOP OF 210MW UNIT OF STATION A

VARIABLE COST = 140 Ps

140

150

160

170

180

190

200

210

49 49.1 49.2 49.3 49.4 49.5 49.6 49.7 49.8 49.9 50 50.1 50.2 50.3 50.4 50.5

FREQ IN HZ --->

GENERATIONIN

MW--->

0

60

120

180

240

300

360

420

UIPRICE-->

STEADY STATE OPERATION

AT 50 HZ GEN= 190MW

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140

150

160

170

180

190

200

210

49 49.1 49.2 49.3 49.4 49.5 49.6 49.7 49.8 49.9 50 50.1 50.2 50.3 50.4 50.5

FREQ IN HZ --->

GENERATIONIN

MW--->

0

60

120

180

240

300

360

420

UIPRICE-->

OVER GENERATED BY 5%

FREQUENCY DIPPED TO 49.8 HZ

GENERATION INCREASED BY 10 MW

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140

150

160

170

180

190

200

210

49 49.1 49.2 49.3 49.4 49.5 49.6 49.7 49.8 49.9 50 50.1 50.2 50.3 50.4 50.5

FREQ IN HZ --->

GENERATIONIN

MW--->

0

60

120

180

240

300

360

420

UIPRICE-->

OVER GENERATED BY 5%

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140

150

160

170

180

190

200

210

49 49.1 49.2 49.3 49.4 49.5 49.6 49.7 49.8 49.9 50 50.1 50.2 50.3 50.4 50.5

FREQ IN HZ --->

GENERATIONIN

MW--->

0

60

120

180

240

300

360

420

UIPRICE-->

STEADY STATE OPERATION

AT 50 HZ GEN= 190MW

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140

150

160

170

180

190

200

210

49 49.1 49.2 49.3 49.4 49.5 49.6 49.7 49.8 49.9 50 50.1 50.2 50.3 50.4 50.5

FREQ IN HZ --->

GENERATIONIN

MW--->

0

60

120

180

240

300

360

420

UIPRICE-->

UI PRICE = 84 Ps

FREQUENCY RISE UPTO 50.2 HZ

GENERATION DECREASED BY 17MW

INITIAL

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5% DROOP OF 210MW UNIT OF STATION B


140

150

160

170

180

190

200

210

49 49.1 49.2 49.3 49.4 49.5 49.6 49.7 49.8 49.9 50 50.1 50.2 50.3 50.4 50.5

FREQ IN HZ --->

GENERATIONIN

MW--->

0

60

120

180

240

300

360

420

UIPRICE-->

UI PRICE = 84 Ps

FREQUENCY RISE UPTO 50.2 HZ

GENERATION DECREASED BY 17MW

INITIAL

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5% DROOP OF 210MW UNIT OF STATION B


140

150

160

170

180

190

200

210

49 49.1 49.2 49.3 49.4 49.5 49.6 49.7 49.8 49.9 50 50.1 50.2 50.3 50.4 50.5

FREQ IN HZ --->

GENERATIONIN

MW--->

0

60

120

180

240

300

360

420

UIPRICE-->

GENERATION INCREASED BY 17MW

FINALSINCE VARIABLE COST OF

STATION B < UI PRICE

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140

150

160

170

180

190

200

210

49 49.1 49.2 49.3 49.4 49.5 49.6 49.7 49.8 49.9 50 50.1 50.2 50.3 50.4 50.5

FREQ IN HZ --->

GENERATIONIN

MW--->

0

60

120

180

240

300

360

420

UIPRICE-->

FINAL

GENERATION FURTHER REDUCED BY

17MW

SINCE VARIABLE COST OF

STATION A > UI PRICE

PROPORTIONAL CONTROL

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Kc

FB

PROPORTIONAL CONTROL

A simple form of control, where the controller

response is proportional to the control error.

Provides immediate controller response to setpoint

change, but speed may not settle exactly on SP usingproportional control alone

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INTEGRAL CONTROL

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FB

fdt1/Tc

INTEGRAL CONTROL

Control action is control error integratedover time.

Integrates the error over time to overcome theoffset from Proportionalalone such that speed =

SP. However, Integral action may cause

overshoot, oscillation and/or instability problems

Kc

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PID Parameter Tuning PI

only

DIFFERENTIAL CONTROL

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FB

df/dtTd

DIFFERENTIAL CONTROL

In dif ferent ia l contro l, control action is based onthe change (derivative) of the control error.

Used to put the reigns on PI control to prevent

overshoot and oscillation and to add stability

Kc

PID CONTROL

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A form of control based on the three basic

types of control: proport ional, integraland

dif ferentialcont ro l. PID Contro l lersare

created by combining P, I and D elements toget the desired control characteristic.

PID CONTROL

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SUPPRESSED GOVERNOR OPERATION
http://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/PIDMOD2.xls

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SUPPRESSED GOVERNOR OPERATION

OPEN

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CERC ORDER ON IEGC DATED 22.02.2002QUOTE

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1.6 Free-Governor Action:

The dates from which the stipulations under sections 4.8(c), 4.8(d), 6.2(e), 6.2(f),

6.2(g) and 6.2(h) would come into effect shall be as under :

(i) All thermal generating units of installed capacity 200 MW and above and reservoir

based hydro units of installed capacity 50 MW and above :

Southern Region }

}

Eastern Region }

}

Northern Region } The date for the

} implementation of theWestern Region } Commercial mechanism

} mentioned in Section 7.1(d)

(ii) All thermal and reservoir based hydro } for the respective region.

generating units of installed capacity }

10 MW and above in North Eastern Region }

(iii) All other generating units - three months after the above dates for the respectiveregions except in the case of Nuclear Power Stations which shall be exempted till the next

review of the IEGC.

Any exemptionfrom the above may be granted only by CERC for which the

concerned constituent shall file a petition in advance.

UNQUOTE


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6.2(e) All generating units, which are synchronised with the grid, irrespective of

their ownership, type and size, shall have their governors in normal operation at all

times. If any generating unit of over fifty (50) MW size (10 MW for North Eastern

Region) is required to be operated without its governor in normal operation, the

RLDC shall be immediately advised about the reason and duration of such

operation. All governors shall have a droop of between 3% and 6%.

6.2(f) Facilities available with/in load limiters, Automatic Turbine Run up System

(ATRS), Turbine supervisory control, coordinated control system, etc. shall not be

used to suppress the normal governor action in any manner. No dead bands and/or

time delays shall be deliberately introduced.

UNQUOTE


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6.2(g) All Generating Units, operating at/up to 100% of their Maximum Continuous

Rating (MCR) shall normally be capable of (and shall not in any way be prevented from)

instantaneously picking up five per cent (5%) extra load for at least five (5) minutes or

within technical limits prescribed by the manufacturer when frequency falls due to a

system contingency. The generating units operating at above 100% of their MCR shall

be capable of (and shall not be prevented from) going at least up to 105% of their MCR

when frequency falls suddenly. Any generating unit of over fifty (50) MW size (10 MW for

NER) not complying with the above requirement, shall be kept in operation

(synchronised with the Regional grid) only after obtaining the permission of RLDC.

However, the constituent can make up the corresponding short fall in spinning reserve

by maintaining an extra spinning reserve on the other generating units of the constituent.

UNQUOTE


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6.2(h) The recommended rate for changing the governor setting, i.e. supplementary

control for increasing or decreasing the output (generation level) for all generating .units,

irrespective of their type and size, would be one (1.0) per cent per minute or as per

manufacturer's limits. However, if frequency falls below 49.5 Hz, all partly loaded

generating units shall pick up additional load at a faster rate, according to their capability.

UNQUOTE

FREE GOVERNOR MODE OF

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OPERATION

Quote

6.2 (c) All generating units, which are synchronised with the

grid, irrespective of their ownership, type and size, shall have

their governors in normal operation at all times. If any

generating unit of over fifty (50) MW size (10 MW for North

Eastern Region) is required to be operated without its governor

in normal operation, the RLDC shall be immediately advised

about the reason and duration of such operation. All governors

shall have a droop of between 3% and 6%.

Unquote

CERC Order ON IEGC dated 21.12.1999

SRLDC Requested all constituents including ISGS vide letter

dated 3rd Jan 03 to take a lead in this matter.

FREE GOVERNOR MODE OF

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OPERATION The matter discussed in 368th OCC meeting

All SR constituents/ISGS agreed to convey their readiness by 21.01.2003

SRLDC again requested all constituents vide letter dt.21.01.03 to intimate unit/station wise status/ programme

Matter discussed in 109th TCC/131st SREB meeting.

ISGS/SR constituents agreed for FGM by 1st May 2003.

Discussed in 369th, 370th, 371st & 372nd OCC meetings.

KSEB & TNEB furnished unit wise/ station wise program/ constraint/ preparedness

APTRANSCO conveyed readiness for FGM of all generators except thermal units of APGENCO

Freq response characteristics calculation details covering 3 events furnished for examination & necessary

feedback by the constituents.

Constituents Actual response Shortfall(AVG) (AVG)

AP 2 % 98 %

KAR 17 % 83 %

KER 29 % 71 %

TN 13 % 87 %

Matter again discussed in 110th TCC/132nd SREB meeting.

All SR constituents/ISGS agreed for FGM by 1st August 2003.

Action by constituents to achieve the target to be discussed.

Present status to be reviewed.

NLY-II U#4LETTERS
http://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/Understand_Calculate_Frequency_Response.pdfhttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/LIST%20OF%20GENERATORS%20TO%20BE%20ON%20FREE%20GOV%20MODE.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/OCC/373RD%20OCC%20MEETING/FREQUENCY%20RESPONSE%20CHARACTERISTICS%20FOR%20JUNE%202003.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xlshttp://localhost/var/www/apps/FREE%20GOVERNOR%20OPERATION/STATUS%20OF%20GENERATORS%20ON%20FGM.xls

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NEYVELI U-4 ON FGM ON 19/06/2003

160

170

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190

200

210

220

11:00 11:15 11:30 11:45 12:00 12:15 12:30 12:45 13:00

49

49.2

49.4

49.6

49.8

50

50.2

50.4

NYL U-4 GENERATION

REDUCTION OF 21 MW IN 5 MTS

FREQUENCY

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Thank you

FGM IN SR

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